UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
 Washington, D.C. 20549
FORM 10-Q
(Mark One)
(Mark One)
x☒
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2017
ORFor the quarterly period ended March 31, 2021
OR
o☐
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from  to
For the transition period from __________ to__________

Commission File Number 1-8097
EnscoValaris plc
(Exact name of registrant as specified in its charter)
England and Wales
98-0635229
(State or other jurisdiction of

incorporation or organization)
6 Chesterfield Gardens
(I.R.S. Employer
Identification No.)
Cannon Place, 78 Cannon Street
London,England
EC4N 6AF
(Address of principal executive offices)
98-0635229
(I.R.S. Employer
Identification No.)
W1J 5BQ
(Zip Code)
Registrant's telephone number, including area code:  +44 (0) 20 7659 4660
  
Securities registered pursuant to Section 12(b) of the Act: None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  Yes x☒  No  o☐


Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  Yes x☒        No  o☐


Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large accelerated filer☐Accelerated filer☒
Large accelerated filerxAccelerated filero
Non-Accelerated filer
o  (Do not check if a smaller reporting company)
☐		Smaller reporting companyo☒
Emerging-growthEmerging growth companyo☐


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.  o☐




Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  o☐No  x☒


As of October 19, 2017,April 23, 2021, there were 436,019,178199,730,533 Class A ordinary shares of the registrant issued and outstanding.




ENSCOVALARIS PLC
INDEX TO FORM 10-Q
FOR THE QUARTER ENDED SEPTEMBER 30, 2017

MARCH 31, 2021
ITEM 1.   FINANCIAL STATEMENTS
Report of Independent Registered Public Accounting Firm
34
Condensed Consolidated Statements of Operations

Three Months Ended September 30, 2017March 31, 2021 and 20162020
45
Condensed Consolidated Statements of Operations
Nine Months Ended September 30, 2017 and 2016
5
Condensed Consolidated Statements of Comprehensive (Loss) Income
Loss
Three Months Ended September 30, 2017March 31, 2021 and 20162020
6
Condensed Consolidated Statements of Comprehensive (Loss) Income
Nine Months Ended September 30, 2017 and 2016
7
Condensed Consolidated Balance Sheets
September 30, 2017
March31, 2021 and December 31, 20162020
87
Condensed Consolidated Statements of Cash Flows
Nine
Three Months Ended September 30, 2017March 31, 2021 and 20162020
98
Notes to Condensed Consolidated Financial Statements
109
ITEM 2.   MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
4341
ITEM 3.   QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
5960
ITEM 4.   CONTROLS AND PROCEDURES
5960
61
ITEM 1.   LEGAL PROCEEDINGS
6061
ITEM 1A. RISK FACTORS
6362
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
6462
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
63
ITEM 6.  EXHIBITS
6563
6664




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; dividends;the outcome and effects of the Chapter 11 Cases (as defined below); expected utilization, day rates, revenues, operating expenses, cash flows, contract terms, contract backlog, capital expenditures, insurance, financing and funding; the timingeffect, impact, potential duration and other implications of availability, delivery, mobilization, contract commencement or relocation or other movement of rigs and the timing thereof; future rig construction (including construction in progress and completion thereof), enhancement, upgrade or repair and timing and cost thereof; the suitability of rigs for future contracts;ongoing COVID-19 pandemic; 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; 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; 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; our program to high-grade the rig fleet by investing in new equipmentoutcome of tax disputes, assessments and divesting selected assetssettlements; synergies and underutilized rigs;expected additional cost savings; dividends; 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 difficult market conditions, our projected negative cash flows in 2021 and highly leveraged balance sheet, including:
•potential adverse effects of the Chapter 11 Cases on our liquidity and results of operations;

•objections to the confirmation of our plan of reorganization or other pleadings we file that could protract the Chapter 11 Cases;

•our ability to successfully integratecomply with the business,restrictions and other covenants imposed by our DIP Credit Agreement (as defined herein) and other financial arrangements;

•the Bankruptcy Court’s rulings in the Chapter 11 Cases, and the outcome of the Chapter 11 Cases generally;

•the length of time that we will operate under chapter 11 protection and the continued availability of operating capital during the pendency of the proceedings;
•the ongoing COVID-19 pandemic, the related public health measures implemented by governments worldwide, the duration and severity of the outbreak and its impact on global oil demand, the volatility in prices for oil and natural gas and the extent of disruptions to our operations;
•downtime or temporary shut down of operations of our rigs as a result of an outbreak of COVID-19 on one or more of our rigs;
•disruptions to the operations and employeesbusiness, as a result of Atwood Oceanics, Inc.the spread of COVID-19, of our key customers, suppliers and other counterparties, including impacts affecting our supply chain and logistics;
•disputes over production levels among members of the Organization of Petroleum Exporting Countries and other oil and gas producing nations (“Atwood”OPEC+”), which could result in increased volatility in prices for oil and to realize synergies and cost savingsnatural gas that could affect the markets for our services;
•decreases in connection with our acquisition of Atwood;

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

1

•delays in contract commencement dates or cancellation, suspension, renegotiation or termination (with or without cause, including due to impacts of the COVID-19 pandemic) of drilling contracts or drilling programs as a result of general and industry-specific economic conditions, mechanical difficulties, performance or other reasons;
•potential additional asset impairments;
•the adequacy of sources of liquidity for us and our customers;
•the reaction of our customers, prospective customers, suppliers and service providers to the Chapter 11 Cases and the related increased performance and credit risks associated with our constrained liquidity position and capital structure;
•our customers, in response to reduced oil price expectations, cancelling or shortening the duration of our drilling contracts, cancelling future drilling programs and seeking pricing and other contract concessions from us;
•the impact of the delisting of our Class A ordinary shares from the New York Stock Exchange ("NYSE") in September 2020;
•our ability to attract and retain skilled personnel on commercially reasonable terms, whether due to labor regulations, unionization, or otherwise, or to retain employees as a result of the imposition of further public health measures due to the COVID-19 pandemic, our financial condition generally or as a result of the Chapter 11 Cases;
•internal control risk due to significant employee reductions;
•changes in worldwide rig supply and demand, competition or technology, including as a result of delivery of newbuild drilling rigs;rigs and governmental policies that could reduce demand for hydrocarbons, including mandating or incentivizing the conversion from internal combustion engine powered vehicles to electric-powered vehicles;

•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 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 assetsassets; 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;

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,rigs 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, and 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;parties;

2

•governmental regulatory, legislative and permitting requirements affecting drilling operations, including limitations on drilling locations (such as the Gulf of Mexico during hurricane season);, limitations on new leases under the current moratorium on oil and gas leasing in U.S. federal lands and waters, and regulatory measures to limit or reduce greenhouse gas emissions;

•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 hurricanesother 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 indebtedness and pursue other business opportunities may be limited by our debt levels, debt agreement restrictions and the credit ratings assigned to our debt by independent credit rating agencies;

the adequacy of sources of liquity 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 or to enforce any payment obligations of the joint venture pursuant to outstanding shareholder notes receivable;
delays in contract commencement dates•activism by our security holders;
•economic volatility and political, legal and tax uncertainties following the U.K. exit from the European Union;
•the occurrence of cybersecurity incidents, attacks or the cancellation of drilling programs by operators;other breaches to our information technology systems, including our rig operating systems; and

•adverse changes in foreign currency exchange rates, including their effect on the fair value measurement of ourany derivative instruments; andinstruments that we may enter into.

potential long-lived asset impairments.

In addition to the numerous risks, uncertainties and assumptions described above, you should also carefully read and consider "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" in Part I and "Item 1A. Risk Factors" in Part II of this report and "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 our annual report on Form 10-K for the year ended December 31, 2016,2020, which is available on the U.S. Securities and Exchange Commission website at www.sec.gov. 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-lookingforward looking statements, except as required by law.


3



PART I - FINANCIAL INFORMATION


Item 1.Financial Statements


REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
TheTo the Board of Directors and Shareholders
EnscoValaris plc:
 

Results of Review of Interim Financial Information
We have reviewed the accompanying condensed consolidated balance sheet of EnscoValaris plc and subsidiaries (the Company) as of September 30, 2017, andMarch 31, 2021, the related condensed consolidated statements of operations and comprehensive (loss) incomeloss for the three-month and nine-month periods ended September 30, 2017March 31, 2021 and 2016, and2020, the related condensed consolidated statements of cash flows for the nine-monththree-month periods ended September 30, 2017March 31, 2021 and 2016. These condensed2020, and the related notes (collectively, the consolidated interim financial statementsinformation). Based on our reviews, we are not aware of any material modifications that should be made to the responsibility of the Company’s management.consolidated interim financial information for it to be in conformity with U.S. generally accepted accounting principles.
We conducted our reviewhave previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States). (PCAOB), the consolidated balance sheet of the Company as of December 31, 2020, and the related consolidated statements of operations, comprehensive loss, and cash flows for the year then ended (not presented herein); and in our report dated March 2, 2021, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, 2020, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.
Inability to Continue as a Going Concern
As indicated in Note 2 of the Company's unaudited condensed consolidated interim financial information as of March 31, 2021 and for the three-month period then ended, certain conditions indicate that the Company may be unable to continue as a going concern. The accompanying unaudited and condensed consolidated interim financial information does not include any adjustments that might result from the outcome of this uncertainty.
Basis for Review Results
This consolidated interim financial information is the responsibility of the Company’s management. 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 reviews in accordance with the standards of the PCAOB. A review of consolidated interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States),PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.
Based on our review, we are not aware of any material modifications that should be made to the condensed consolidated financial statements referred to above for them to be in conformity with U.S. generally accepted accounting principles.
We have previously audited, in accordance with standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of Ensco plc and subsidiaries as of December 31, 2016 and the related consolidated statements of operations, comprehensive income (loss), and cash flows for the year then ended (not presented herein); and in our report dated February 28, 2017, we expressed an unqualified opinion on those consolidated financial statements.In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, 2016, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.
 
/s/ KPMG LLP
 
Houston, Texas
October 26, 2017

April 28, 2021

4
ENSCO

VALARIS PLC AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In millions, except per share amounts)
(Unaudited)
 Three Months Ended
September 30,
 2017 2016
OPERATING REVENUES$460.2
 $548.2
OPERATING EXPENSES   
Contract drilling (exclusive of depreciation)285.8
 298.1
Depreciation108.2
 109.4
General and administrative30.4
 25.3
 424.4
 432.8
OPERATING INCOME35.8
 115.4
OTHER INCOME (EXPENSE)   
Interest income7.5
 3.8
Interest expense, net(48.1) (53.4)
Other, net.2
 18.7
 (40.4) (30.9)
(LOSS) INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES(4.6) 84.5
PROVISION FOR INCOME TAXES   
Current income tax expense (benefit)14.9
 (5.7)
Deferred income tax expense8.5
 2.2
 23.4
 (3.5)
(LOSS) INCOME FROM CONTINUING OPERATIONS(28.0) 88.0
LOSS FROM DISCONTINUED OPERATIONS, NET(.2) (.7)
NET (LOSS) INCOME(28.2) 87.3
NET LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS2.8
 (2.0)
NET (LOSS) INCOME ATTRIBUTABLE TO ENSCO$(25.4) $85.3
(LOSS) EARNINGS PER SHARE - BASIC AND DILUTED   
Continuing operations$(0.08) $0.28
Discontinued operations—
 —
 $(0.08) $0.28
    
NET (LOSS) INCOME ATTRIBUTABLE TO ENSCO SHARES - BASIC AND DILUTED$(25.5) $83.5
    
WEIGHTED-AVERAGE SHARES OUTSTANDING   
Basic and Diluted301.2
 298.6
    
CASH DIVIDENDS PER SHARE$0.01
 $0.01
The accompanying notes are an integral part of these condensed consolidated financial statements.


ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In millions, except per share amounts)
(Unaudited)
 Nine Months Ended
September 30,
 2017 2016
OPERATING REVENUES$1,388.8
 $2,271.8
OPERATING EXPENSES   
Contract drilling (exclusive of depreciation)855.2
 1,012.0
Depreciation325.3
 335.1
General and administrative86.9
 76.1
 1,267.4
 1,423.2
OPERATING INCOME121.4
 848.6
OTHER INCOME (EXPENSE) 
  
Interest income22.3
 8.6
Interest expense, net(167.0) (172.5)
Other, net(6.6) 278.3
 (151.3) 114.4
(LOSS) INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES(29.9) 963.0
PROVISION FOR INCOME TAXES   
Current income tax expense32.3
 81.0
Deferred income tax expense34.5
 23.6
 66.8
 104.6
(LOSS) INCOME FROM CONTINUING OPERATIONS(96.7) 858.4
LOSS FROM DISCONTINUED OPERATIONS, NET(.4) (1.8)
NET (LOSS) INCOME(97.1) 856.6
NET LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS.5
 (5.4)
NET (LOSS) INCOME ATTRIBUTABLE TO ENSCO$(96.6) $851.2
(LOSS) EARNINGS PER SHARE - BASIC AND DILUTED   
Continuing operations$(0.32) $3.07
Discontinued operations—
 —
 $(0.32) $3.07
    
NET (LOSS) INCOME ATTRIBUTABLE TO ENSCO SHARES - BASIC AND DILUTED$(96.9) $836.1
  
  
WEIGHTED-AVERAGE SHARES OUTSTANDING   
Basic and Diluted300.9
 272.0
    
CASH DIVIDENDS PER SHARE$0.03
 $0.03
The accompanying notes are an integral part of these condensed consolidated financial statements.


ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME
(In millions)
(Unaudited)
 Three Months Ended
September 30,
 2017 2016
    
NET (LOSS) INCOME$(28.2) $87.3
OTHER COMPREHENSIVE INCOME (LOSS), NET   
Net change in derivative fair value1.7
 —
Reclassification of net (income) losses on derivative instruments from other comprehensive income into net (loss) income(.1) 2.2
Other.1
 (.5)
NET OTHER COMPREHENSIVE INCOME1.7
 1.7
    
COMPREHENSIVE (LOSS) INCOME(26.5) 89.0
COMPREHENSIVE LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS2.8
 (2.0)
COMPREHENSIVE (LOSS) INCOME ATTRIBUTABLE TO ENSCO$(23.7) $87.0

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


ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME
(In millions)
(Unaudited)
 Nine Months Ended
September 30,
 2017 2016
    
NET (LOSS) INCOME$(97.1) $856.6
OTHER COMPREHENSIVE INCOME, NET   
Net change in derivative fair value7.7
 (.6)
Reclassification of net losses on derivative instruments from other comprehensive income into net (loss) income1.1
 10.1
Other.8
 (.5)
NET OTHER COMPREHENSIVE INCOME9.6
 9.0
    
COMPREHENSIVE (LOSS) INCOME(87.5) 865.6
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS.5
 (5.4)
COMPREHENSIVE (LOSS) INCOME ATTRIBUTABLE TO ENSCO$(87.0) $860.2

Three Months Ended
March 31,
20212020
OPERATING REVENUES$307.1 $456.6 
OPERATING EXPENSES 
Contract drilling (exclusive of depreciation)252.2 476.0 
Loss on impairment756.5 2,808.2 
Depreciation122.1 164.5 
General and administrative24.3 53.4 
Total operating expenses1,155.1 3,502.1 
EQUITY IN EARNINGS (LOSSES) OF ARO1.9 (6.3)
OPERATING LOSS(846.1)(3,051.8)
OTHER INCOME (EXPENSE)
Interest income2.6 4.8 
Interest expense, net (Unrecognized contractual interest expense for debt subject to compromise was $100.3 million for the three months ended March 31, 2021)(1.3)(113.2)
Reorganization items, net(52.2)0 
Other, net21.1 .5 
 (29.8)(107.9)
LOSS BEFORE INCOME TAXES(875.9)(3,159.7)
PROVISION (BENEFIT) FOR INCOME TAXES
Current income tax expense (benefit)30.8 (72.5)
Deferred income tax expense (benefit).9 (79.5)
 31.7 (152.0)
NET LOSS(907.6)(3,007.7)
NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS(2.4)1.4 
NET LOSS ATTRIBUTABLE TO VALARIS$(910.0)$(3,006.3)
LOSS PER SHARE - BASIC AND DILUTED$(4.56)$(15.19)
WEIGHTED-AVERAGE SHARES OUTSTANDING
Basic and Diluted199.6 197.9 
The accompanying notes are an integral part of these condensed consolidated financial statements.

5



ENSCOVALARIS PLC AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONDENSED CONSOLIDATED BALANCE SHEETSSTATEMENTS OF COMPREHENSIVE LOSS
(In millions, except share and par value amounts)
millions)
 September 30,
2017		 December 31,
2016
 (Unaudited)  
ASSETS
CURRENT ASSETS   
    Cash and cash equivalents$724.4
 $1,159.7
    Short-term investments1,069.8
 1,442.6
    Accounts receivable, net349.0
 361.0
    Other318.3
 316.0
Total current assets2,461.5
 3,279.3
PROPERTY AND EQUIPMENT, AT COST13,492.6
 12,992.5
    Less accumulated depreciation2,396.2
 2,073.2
       Property and equipment, net11,096.4
 10,919.3
OTHER ASSETS, NET125.0
 175.9
 $13,682.9
 $14,374.5
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES   
Accounts payable - trade$187.9
 $145.9
Accrued liabilities and other300.8
 376.6
Current maturities of long-term debt—
 331.9
Total current liabilities488.7
 854.4
LONG-TERM DEBT4,747.7
 4,942.6
OTHER LIABILITIES279.2
 322.5
COMMITMENTS AND CONTINGENCIES

 

ENSCO SHAREHOLDERS' EQUITY 
  
Class A ordinary shares, U.S. $.10 par value, 314.9 million and 310.3 million shares issued as of September 30, 2017 and December 31, 201631.5
 31.0
Class B ordinary shares, £1 par value, 50,000 shares authorized and issued as of September 30, 2017 and December 31, 2016.1
 .1
Additional paid-in capital6,429.8
 6,402.2
Retained earnings1,744.2
 1,864.1
Accumulated other comprehensive income28.6
 19.0
Treasury shares, at cost, 11.0 million and 7.3 million shares as of September 30, 2017 and December 31, 2016(69.0) (65.8)
Total Ensco shareholders' equity8,165.2
 8,250.6
NONCONTROLLING INTERESTS2.1
 4.4
Total equity8,167.3
 8,255.0
 $13,682.9
 $14,374.5
(Unaudited)
Three Months Ended
March 31,
20212020
NET LOSS$(907.6)$(3,007.7)
OTHER COMPREHENSIVE LOSS, NET  
Net change in fair value of derivatives0 (12.9)
Net reclassification adjustment for amounts recognized in net loss as a component of net periodic benefit cost.1 0 
Reclassification of net gains on derivative instruments from other comprehensive loss into net loss(5.6)(.1)
Other.2 (.4)
NET OTHER COMPREHENSIVE LOSS(5.3)(13.4)
COMPREHENSIVE LOSS(912.9)(3,021.1)
COMPREHENSIVE (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS(2.4)1.4 
COMPREHENSIVE LOSS ATTRIBUTABLE TO VALARIS$(915.3)$(3,019.7)

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

6


ENSCOVALARIS PLC AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWSBALANCE SHEETS
(In millions)millions, except share and par value amounts)
(Unaudited)
 Nine Months Ended
September 30,
 2017 2016
OPERATING ACTIVITIES 
  
Net (loss) income$(97.1) $856.6
Adjustments to reconcile net (loss) income to net cash provided by operating activities of continuing operations:   
Depreciation expense325.3
 335.1
Deferred income tax expense34.5
 23.6
Share-based compensation expense31.3
 28.7
Amortization of intangibles and other, net(8.7) (16.2)
Loss (gain) on debt extinguishment2.6
 (279.0)
Other(.3) (2.9)
Changes in operating assets and liabilities(68.0) 48.9
Net cash provided by operating activities of continuing operations219.6
 994.8
    
INVESTING ACTIVITIES   
Maturities of short-term investments1,412.7
 1,582.0
Purchases of short-term investments(1,040.0) (1,704.0)
Additions to property and equipment(474.1) (255.5)
Other 2.6
 7.7
Net cash used in investing activities of continuing operations(98.8) (369.8)
    
FINANCING ACTIVITIES   
Reduction of long-term borrowings(537.0) (862.4)
Cash dividends paid(9.4) (8.5)
Debt issuance costs(5.5) —
Proceeds from equity issuance—
 585.5
Other(4.5) (2.3)
Net cash used in financing activities(556.4) (287.7)
    
Net cash (used in) provided by discontinued operations(.4) 7.4
Effect of exchange rate changes on cash and cash equivalents.7
 (.6)
(DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS(435.3) 344.1
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD1,159.7
 121.3
CASH AND CASH EQUIVALENTS, END OF PERIOD$724.4
 $465.4

March 31,
2021		December 31,
2020
(Unaudited)
ASSETS
CURRENT ASSETS  
    Cash and cash equivalents$291.7 $325.8 
    Accounts receivable, net449.8 449.2 
    Other current assets383.5 397.9 
Total current assets1,125.0 1,172.9 
PROPERTY AND EQUIPMENT, AT COST12,125.9 13,209.3 
    Less accumulated depreciation2,042.0 2,248.8 
       Property and equipment, net10,083.9 10,960.5 
LONG-TERM NOTES RECEIVABLE FROM ARO442.7 442.7 
INVESTMENT IN ARO122.8 120.9 
OTHER ASSETS172.5 176.2 
 $11,946.9 $12,873.2 
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES  
Accounts payable - trade$176.8 $176.4 
Accrued liabilities and other290.6 250.4 
Total current liabilities467.4 426.8 
OTHER LIABILITIES704.6 762.4 
Total liabilities not subject to compromise1,172.0 1,189.2 
LIABILITIES SUBJECT TO COMPROMISE7,313.7 7,313.7 
COMMITMENTS AND CONTINGENCIES00
VALARIS SHAREHOLDERS' EQUITY  
Class A ordinary shares, U.S. $0.40 par value, 206.1 million shares issued as of March 31, 2021 and December 31, 202082.5 82.5 
Class B ordinary shares, £1 par value, 50,000 shares issued as of March 31, 2021 and December 31, 2020.1 .1 
Additional paid-in capital8,643.5 8,639.9 
Retained deficit(5,093.8)(4,183.8)
Accumulated other comprehensive loss(93.2)(87.9)
Treasury shares, at cost, 6.4 million and 6.6 million shares as of March 31, 2021 and December 31, 2020, respectively(76.0)(76.2)
Total Valaris shareholders' equity3,463.1 4,374.6 
NONCONTROLLING INTERESTS(1.9)(4.3)
Total equity3,461.2 4,370.3 
 $11,946.9 $12,873.2 
The accompanying notes are an integral part of these condensed consolidated financial statements.

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ENSCOVALARIS PLC AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions)
(Unaudited)
 Three Months Ended
March 31,
 20212020
OPERATING ACTIVITIES  
Net loss$(907.6)$(3,007.7)
Adjustments to reconcile net loss to net cash used in operating activities:
Loss on impairment756.5 2,808.2 
Depreciation expense122.1 164.5 
Amortization, net(4.6)2.8 
Share-based compensation expense3.8 7.8 
Equity in losses (earnings) of ARO(1.9)6.3 
Deferred income tax expense (benefit).9 (79.5)
Debt discounts and other0 14.2 
Adjustment to gain on bargain purchase0 6.3 
Gain on debt extinguishment0 (3.1)
Other.4 9.7 
   Changes in operating assets and liabilities20.9 (129.9)
   Contributions to pension plans and other post-retirement benefits(22.2)(4.0)
Net cash used in operating activities(31.7)(204.4)
INVESTING ACTIVITIES  
Additions to property and equipment(6.0)(36.3)
Net proceeds from disposition of assets3.7 10.4 
Net cash used in investing activities(2.3)(25.9)
FINANCING ACTIVITIES  
Borrowings on credit facility0 343.9 
Repayments of credit facility borrowings0 (15.0)
Reduction of long-term borrowings0 (9.7)
Other0 (.9)
Net cash provided by financing activities0 318.3 
Effect of exchange rate changes on cash and cash equivalents(.1)(.3)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS(34.1)87.7 
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD325.8 97.2 
CASH AND CASH EQUIVALENTS, END OF PERIOD$291.7 $184.9 

The accompanying notes are an integral part of these condensed consolidated financial statements.
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VALARIS PLC AND SUBSIDIARIES (DEBTOR-IN-POSSESSION)
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)


Note 1 -Unaudited Condensed Consolidated Financial Statements
 
We prepared the accompanying condensed consolidated financial statements of EnscoValaris plc and subsidiaries (the "Company," "Ensco,"Valaris," "our," "we" or "us") in accordance with accounting principles generally accepted in the United States of America ("GAAP"), pursuant to the rules and regulations of the Securities and Exchange Commission (the "SEC") included in the instructions to Form 10-Q and Article 10 of Regulation S-X. The financial information included in this report is unaudited but, in our opinion, includes all adjustments (consisting of normal recurring adjustments) that are necessary for a fair presentation of our financial position, results of operations and cash flows for the interim periods presented. The December 31, 2016 condensed consolidated balance sheet2020 Condensed Consolidated Balance Sheet data werewas derived from our 20162020 audited consolidated financial statements but dodoes not include all disclosures required by GAAP. The preparation of our condensed consolidated financial statements 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.
 
The financial data for the three-monththree months ended March 31, 2021 and nine-month periods ended September 30, 2017 and 20162020 included herein have been subjected to a limited review by KPMG LLP, our independent registered public accounting firm. The accompanying independent registered public accounting firm's review report is not a report within the meaning of Sections 7 and 11 of the Securities Act, and the independent registered public accounting firm's liability under Section 11 does not extend to it.
 
Results of operations for the three-month and nine-month periodsthree months ended September 30, 2017March 31, 2021 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2017.2021. We recommend these condensed consolidated financial statements be read in conjunction with our annual report on Form 10-K for the year ended December 31, 20162020, filed with the SEC on March 2, 2021.

Chapter 11 Cases and Restructuring Support Agreement

On August 19, 2020 (the "Petition Date"), Valaris plc and certain of its direct and indirect subsidiaries (collectively, the "Debtors"), filed voluntary petitions for reorganization under chapter 11 of the United States Bankruptcy Code ("Bankruptcy Code") in the Bankruptcy Court for the Southern District of Texas (the "Bankruptcy Court"). The Debtors obtained joint administration of their chapter 11 cases under the caption In re Valaris plc, et al., Case No. 20-34114 (MI)(the "Chapter 11 Cases"). On August 18, 2020, the Debtors entered into the Restructuring Support Agreement (the "Original RSA") with certain senior note holders (collectively, the "Consenting Noteholders"). On February 28, 2017 and our quarterly reports on Form 10-Q filed5, 2021, the Debtors entered into the Amended Restructuring Support Agreement (the “Amended RSA”) with the SEC on April 27, 2017Consenting Noteholders and July 27, 2017.

Operating Revenues and Expenses

During the nine-month period ended September 30, 2016, operating revenues included $185.0 million for the lump-sum consideration received in settlement and releaseholders of 100% of the ENSCO DS-9 customer's ongoing early terminationtotal commitments under our revolving credit facility (the “Consenting Lenders” and, together with the Consenting Noteholders, the “Consenting Creditors”), which contemplates that the Company will implement the restructuring through the Chapter 11 Cases pursuant to a plan of reorganization and the various related transactions set forth in or contemplated by the Amended RSA. On March 3, 2021, the Bankruptcy Court confirmed the Debtors' chapter 11 plan of reorganization. Although the Company expects to emerge from chapter 11 imminently, there can be no assurance that we will consummate a plan of reorganization as contemplated by the Amended RSA or complete another plan of reorganization with respect to the Chapter 11 Cases.

See“Note 2 – Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional details regarding the Chapter 11 Cases and Amended RSA.
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Bankruptcy Accounting

The condensed consolidated financial statements included herein have been prepared as if we were a going concern. See “Note 2 – Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional details regarding the bankruptcy and circumstances raising substantial doubt over our ability to continue as a going concern. As a result, we have segregated liabilities and obligations whose treatment and $20.0 million forsatisfaction are dependent on the lump-sum consideration received in settlementoutcome of the ENSCO 8503 customer's remaining obligations underChapter 11 Cases and have classified these items as "Liabilities Subject to Compromise” on our Condensed Consolidated Balance Sheets. In addition, we have classified all income, expenses, gains or losses that were incurred or realized as a result of the contract. The ENSCO DS-9 contract was terminatedChapter 11 Cases subsequent to the Petition Date as “Reorganization Items” in our Condensed Consolidated Statements of Operations.

We anticipate that we will adopt fresh start accounting upon our emergence from chapter 11, becoming a new entity for conveniencefinancial reporting purposes. As a result, upon emergence, the Company’s assets and liabilities will generally be reported at fair value and will reconcile to the enterprise value confirmed by the customer in July 2015, wherebyBankruptcy Court. These fair values are expected to differ materially from the amounts reflected on our customer was obligated to pay us monthly termination fees for two years under the termination provisions of the contract. The ENSCO 8503 contract was originally scheduled to expire in August 2017.historical balance sheet.


New Accounting Pronouncements


Recently adopted accounting pronouncements
Income Taxes - In August 2017,December 2019, the Financial Accounting Standards Board (the "FASB"("FASB")issued Update 2017-12, Derivatives and HedgingASU 2019-12, Income Taxes (Topic 815)740): Targeted Improvements toSimplifying the Accounting for Hedging Activities Income Taxes ("Update 2017-12"2019-12"), which will make more hedging strategies eligibleremoves certain exceptions for hedge accounting. It also amends presentation and disclosure requirements and changes how companies assess effectiveness. This update is effective for annualinvestments, intraperiod allocations and interim periods beginningtax calculations and adds guidance to reduce complexity in accounting for income taxes. The various amendments in Update 2019-12 are applied on a retrospective basis, modified retrospective basis and prospective basis, depending on the amendment. We adopted Update 2019-12 effective January 1, 2021 with no material impact to our financial statements upon adoption.

Accounting pronouncements to be adopted

Reference Rate Reform - In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting ("Update 2020-04"), which provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met. The amendments in Update 2020-04 apply only to contracts, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. The expedients and exceptions provided by the amendments do not apply to contract modifications made and hedging relationships entered into or evaluated after December 15, 2018, with early adoption permitted.31, 2022, except for hedging relationships existing as of December 31, 2022, for which an entity has elected certain optional expedients and that are retained through the end of the hedging relationship. The provisions in Update 2020-04 are effective upon issuance and can be applied prospectively through December 31, 2022. We are currentlyin the process of evaluating the effect that Update 2017-12impact this amendment will have on our condensed consolidated financial statements and related disclosures.statements.




Convertible Instruments - In October 2016,August 2020, the FASB issued Accounting Standards ASU 2020-06, “Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815 – 40)” ("Update 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers2020-06”). ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of Assets Other Than Inventory (“Update 2016-16”), which requires entities to recognize the income tax consequences ofliabilities and equity, including convertible instruments and contracts in an intra-entity transfer of an asset other than inventory when the transaction occurs as opposed to deferring tax consequences and amortizing them into future periods. We adopted Update 2016-16 on a modified retrospective basis effective January 1, 2017. As a result of modified retrospective application, we reduced prepaid taxes on intercompany transfers of property and related deferred tax liabilities resulting in the recognition of a cumulative-effect reduction in retained earnings of $14.1 million on our condensed consolidated balance sheet as of January 1, 2017. We do not expect a material impact to our 2017 operating results as a resultentity’s own equity. The ASU is part of the adoption of Update 2016-16.
In March 2016, the FASB issued Accounting Standards Update 2016-09, Compensation — Stock Compensation (Topic 718): ImprovementsFASB’s simplification initiative, which aims to Employee Share-Based Payment Accounting ("Update 2016-09"), which simplifies several aspects of accounting for share-based payment transactions including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. We adopted Update 2016-09reduce unnecessary complexity in GAAP. The ASU’s amendments are effective January 1, 2017. Our adoption of Update 2016-09 did not result in any cumulative effect on retained earnings and no adjustments have been made to prior periods. The new standard will cause volatility in our effective tax rates primarily due to the new requirement to recognize additional tax benefits or expenses in earnings related to the vesting or settlement of employee share-based awards, rather than in additional paid-in capital, during the period in which they occur. Furthermore, forfeitures are now recorded as they occur as opposed to estimating an allowance for future forfeitures.

During 2014, the FASB issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606) ("Update 2014-09"), which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. Update 2014-09 is effective for annual and interim periods for fiscal years beginning after December 15, 2017. Subsequent to the issuance of Update 2014-09, the FASB issued several additional Accounting Standards Updates to clarify implementation guidance, provide narrow-scope improvements and provide additional disclosure guidance. Update 2014-09 will replace most existing revenue recognition guidance in U.S. GAAP and may be adopted using a retrospective, modified retrospective or prospective with a cumulative catch-up approach. Due to the significant interaction between Update 2014-09 and Accounting Standards Update 2016-02, Leases (Topic 842): Amendments to the FASB Accounting Standards Codification ("Update 2016-02"), we expect to adopt Update 2014-09 and Update 2016-02 concurrently with an effective date of January 1, 2018. We expect to apply the modified retrospective approach to our adoption. We are currently evaluating the effect that Update 2014-09 and Update 2016-02 will have on our consolidated financial statements and related disclosures.

In February 2016, the FASB issued 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 annual2021, and interim periods within those fiscal years, with early adoption permitted no earlier than fiscal years beginning after December 15, 2018,2020. We are in the process of evaluating the impact this amendment may have on our condensed consolidated financial statements.

10

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 condensed consolidated financial statements.

Note 2 -Chapter 11 Proceedings and Ability to Continue as a Going Concern

Chapter 11 Cases

On August 19, 2020, the Debtors filed voluntary petitions for reorganization under chapter 11 of the Bankruptcy Code in the Bankruptcy Court. The Debtors obtained joint administration of the Chapter 11 Cases under the caption In re Valaris plc, et al., Case No. 20-34114 (MI). On March 3, 2021, the Bankruptcy Court confirmed the Debtors' chapter 11 plan of reorganization. Although the Company expects to emerge from chapter 11 imminently, there can be no assurance that we will consummate a plan of reorganization as contemplated by the Amended RSA or complete another plan of reorganization with early adoption permitted.respect to the Chapter 11 Cases.

Until the date of emergence, the Debtors continue to operate their businesses and manage their properties as "debtors-in-possession" under the jurisdiction of the Bankruptcy Court and in accordance with applicable provisions of the Bankruptcy Code and orders of the Bankruptcy Court. As part of the Chapter 11 Cases, the Debtors filed with the Bankruptcy Court motions seeking a variety of "first-day" relief, all of which were granted and have enabled the Company to continue operating without interruption or disruption to its relationships with its customers and vendors or its high-quality service delivery. In particular, employee pay and benefits are expected to continue without interruption.

Restructuring Support Agreement

On August 18, 2020, the Debtors entered into the Original RSA with the Consenting Noteholders. On February 5, 2021, the Debtors entered into the Amended RSA with the Consenting Noteholders and the Consenting Lenders. The Amended RSA contemplates that the Company will implement the restructuring through the Chapter 11 Cases pursuant to a plan of reorganization and the various related transactions set forth in or contemplated by the Amended RSA. Below is a summary of the treatment that the stakeholders of the Company would receive under a plan of reorganization pursuant to the terms of the Amended RSA:

•Holders of the Company's outstanding senior notes ("Senior Notes") will receive their pro rata share of (1) approximately 39% of new common stock issued after consummation of the restructuring (the “New Equity”) and (2) approximately 97.6% of the subscription rights to participate in the rights offering (the "Rights Offering") through which the Company will offer $550 million of new first lien secured notes (the "New Secured Notes"), which includes the Backstop Premium (as defined below);

•Holders of the Senior Notes who participate in the Rights Offering will receive their pro ratashare of approximately 29.3% of the New Equity, together with the RCF Lenders (as defined below) who will receive their pro rata share of approximately 0.7% of the New Equity; and senior noteholders who agreed to backstop the Rights Offering will receive their pro rata share of approximately 2.63% of the New Equity, together with 0.07% of the New Equity reserved for RCF Lenders, approximately $48.8 million in New Secured Notes reserved for the holders of the Senior Notes and approximately $1.2 million in New Secured Notes reserved for the RCF Lenders (the "Backstop Premium");

•Senior noteholders, solely with respect to Pride International LLC's ("Pride") 6.875% senior notes due 2020 and 7.875% senior notes due 2040, Ensco International 7.20% Debentures due 2027, and the Company's 4.875% senior notes due 2022, 4.75% senior notes due 2024, 7.375% senior notes due 2025, 5.4% senior notes due 2042 and 5.85% senior notes due 2044, will receive an aggregate cash payment of $26 million in connection with settlement of certain alleged claims against the Company;

11

•Lenders under the revolving credit facility (“RCF Lenders”) were provided an option to select between two alternative treatments: (1) the ability to participate on a pro rata basis in up to 14% of the Rights Offering plus a recovery of up to 30.8% of the New Equity and up to $45.0 million in cash, or (2) a pro rata recovery of up to 27.8% of the New Equity and up to $116.2 million in cash. Following the results of that election, the two RCF Lenders who chose to participate in the Rights Offering will receive their pro rata share of (1) approximately 5.3% of the New Equity, (2) approximately 2.4% of the New Secured Notes (and associated New Equity), (3) approximately $7.8 million in cash, and (iv) their pro rata share of the Backstop Premium. The RCF Lenders who entered into the Amended RSA and elected not to participate in the Rights Offering will receive their pro rata share of (1) approximately 23.0% of the New Equity, and (2) approximately $96.1 million in cash;

•Holders of general unsecured claims will receive payment in full or reinstatement pursuant to the Bankruptcy Code (excluding claims against the entities party to, or guaranteeing, the new build contracts to be rejected by the Company, which shall receive their liquidation value unless otherwise agreed);

•Holders of our existing Class A modified retrospective approach is required. Duringordinary shares will each receive their pro rata share of 7-year warrants to purchase up to 7% of New Equity (subject to dilution), with a strike price set at a price per share equal to the value at which the senior noteholders would receive a 100% recovery on their claims including accrued interest up to the Petition Date, as applicable; and

•To the extent amounts are borrowed under the DIP Facility (as described below), lenders under the DIP Facility will receive payment in full in cash, unless otherwise agreed and certain other fees owed to the DIP Facility lenders.

The Original RSA provided that for a period of 15 business days after the commencement of the Chapter 11 Cases (the “Joinder Period”), qualified holders of Senior Notes claims, including the Consenting Noteholders, were eligible to become backstop parties (the “Noteholder Backstop Parties”). All Noteholder Backstop Parties were required to join the Original RSA. The expiration of the Joinder Period was extended on September 10, 2020 to September 14, 2020, upon which date we had support for the Original RSA from holders of approximately 72% of the aggregate amount of our evaluationSenior Notes outstanding.

The Amended RSA contemplates that holders of Update 2016-02,claims under the Company’s revolving credit facility also are eligible to become backstop parties (the “Lender Backstop Parties” and, together with the Noteholder Backstop Parties, the "Backstop Parties"). The Lender Backstop Parties are required to join the Amended RSA. As of the execution of the Amended RSA, we have concludedhad support for the transactions contemplated by the Amended RSA from holders of 100% of the total commitments under our revolving credit facility in addition to the holders of approximately 72% of the aggregate amount of our outstanding Senior Notes who supported the Original RSA.

The Amended RSA contains certain covenants on the part of Valaris and the Consenting Creditors, including commitments by the Consenting Creditors to vote in favor of a plan of reorganization and commitments of Valaris and the Consenting Creditors to negotiate in good faith to finalize the documents and agreements governing the restructuring. The Amended RSA also provides for certain conditions to the obligations of the parties and for termination upon the occurrence of certain events, including without limitation, the failure to achieve certain milestones and certain breaches by the parties under the Amended RSA.

Subject to certain exceptions, under the Bankruptcy Code, the filing of the Chapter 11 Cases automatically enjoined, or stayed, the continuation of most judicial or administrative proceedings or filing of other actions against the Debtors or their property to recover, collect or secure a claim arising prior to the date of the Chapter 11 Cases. Notwithstanding the general applicability of the automatic stay described above, governmental authorities may determine to continue actions brought under their regulatory powers.

12

On March 3, 2021, the Bankruptcy Court confirmed the Debtors' chapter 11 plan of reorganization, which incorporated the terms of the restructuring as set forth in the Amended RSA. Although the Company expects to emerge from chapter 11 imminently, there can be no assurance that our drilling contracts contain a lease component, and upon adoption, we will be requiredsuccessful in completing a restructuring or any other similar transaction on the terms set forth in the Amended RSA, on different terms or at all. Among other things, the Amended RSA includes an outside date milestone requiring the Company’s emergence from chapter 11 by no later than June 15, 2021 (subject to separately recognize revenuesa potential 60-day extension pursuant to the terms of the Amended RSA).

Debtor in Possession Facility

On August 11, 2020, prior to the commencement of the Chapter 11 Cases, certain of the Company’s existing noteholders (or their affiliates or designees) provided the Company with a commitment for a senior secured superpriority debtor-in-possession term loan credit facility in an aggregate principal amount of up to $500.0 million (the “DIP Facility”). On September 25, 2020, following approval by the Bankruptcy Court, the Debtors entered into a senior secured superpriority debtor-in-possession term loan credit agreement (the “DIP Credit Agreement”), by and among the Company and certain wholly owned subsidiaries of the Company, as borrowers, the lenders party thereto and Wilmington Savings Fund Society, FSB, as administrative agent and security trustee, in an aggregate amount not to exceed $500.0 million. Borrowings on the DIP Facility will be used to finance, among other things, the ongoing general corporate needs of the Debtors during the course of the Chapter 11 Cases and to pay certain fees, costs and expenses associated with the leaseDebtors’ Chapter 11 Cases.

The maturity date of our drilling rigsthe DIP Credit Agreement is the earliest of (1) August 17, 2021, (2) acceleration of the loans under the DIP Facility and termination of the lenders' commitments under the DIP Facility, (3) the substantial consummation of any plan filed in the Chapter 11 Cases that is confirmed pursuant to an order entered by the Bankruptcy Court and (4) the consummation of a sale of all or substantially all of the assets of the Company and the provisionother Debtors under section 363 of contract drilling services. Duethe Bankruptcy Code. Loans under the DIP Credit Agreement accrue interest at a rate of 8.00% per annum, if paid in kind, and at a rate of 7.00% per annum, if paid in cash.

The DIP Credit Agreement contains a requirement that the Company and any other borrowers provide every four weeks, a rolling 13 week budget to be approved by the required lenders (the “Approved Budget”). The Company and any other borrower that becomes party to the significant interactionDIP Credit Agreement may not vary from the Approved Budget by more than 15% of the forecasted amounts in any forecast period. The Approved Budget is, subject to certain exceptions and is tested at certain times in accordance with the DIP Credit Agreement in order to measure variances between Update 2016-02the actual total cash disbursements (excluding professional fees and Update 2014-09,certain other items consistent with the initial Approved Budget) and the disbursements budgeted for the applicable period.

The DIP Credit Agreement contains events of default customary to debtor-in-possession financings, including events related to the Chapter 11 Cases, the occurrence of which could result in the acceleration of the Debtors’obligation to repay the outstanding indebtedness under the DIP Credit Agreement. The Debtors’ obligations under the DIP Credit Agreement are secured by a security interest in, and lien on, substantially all present and after acquired property (subject to certain exceptions) of the Debtors and are guaranteed by certain of the Company’s subsidiaries, including other Debtors.

The DIP Credit Agreement also contains customary covenants that limit the ability of the Company and its subsidiaries to, among other things, (1) incur additional indebtedness and permit liens to exist on their assets, (2) pay dividends or make certain other restricted payments, (3) sell assets and (4) make certain investments. These covenants are subject to exceptions and qualifications as set forth in the DIP Credit Agreement.

As of March 31, 2021, we expectwere in compliance with our covenants under the DIP Credit Agreement. Additionally, as of March 31, 2021, we had 0 borrowings outstanding against our DIP Facility.

13

Backstop Commitment Agreement

On August 18, 2020, the Company entered into a Backstop Commitment Agreement (the “Initial BCA”) with the initial Backstop Parties. The Initial BCA was amended on September 10, 2020, January 22, 2021 and February 5, 2021 (as so amended, the “Amended BCA”).

Pursuant to adopt both updates concurrentlythe Amended BCA, each of the Backstop Parties will purchase its pro-rata portion (based on an adjusted claims value) of (1) $187.5 million of the New Secured Notes held back for purchase by the Backstop Parties, (the "Holdback Notes"), (2) all of the New Secured Notes offered to Backstop Parties as part of the $312.5 million New Secured Notes offered to all claim holders (the “General Rights Offering”) and (3) New Secured Notes not purchased by non-Backstop Parties in the General Rights Offering. Pursuant to the Amended BCA, certain holders of claims related to the revolving credit facility will be entitled to, among other things, 2.427% of the Holdback Notes and the New Secured Notes (together with ancertain stapled participation equity) offered in the General Rights Offering, as well as a portion of the equity premium payable to all Backstop Parties consisting of 2.7% of New Valaris Equity and Backstop Premium payable in $50.0 million in New Secured Notes.

In each instance, 30% of the new shares issued and outstanding immediately after the effective date of January 1, 2018. Adoptionthe plan of reorganization (subject to dilution by the new warrants and the management incentive plan) will result in increased disclosurebe allocated proportionally to purchasers of the natureNew Secured Notes for no additional consideration. Additionally, in exchange for providing the Backstop Commitments, the Company has agreed to pay the Backstop Parties a Backstop Premium in an aggregate amount equal to $50.0 million payable in New Secured Notes on the effective date of a plan of reorganization, in addition to 2.7% of New Valaris Equity. Further, the Debtors paid a commitment fee of $20.0 million, in cash prior to the Petition Date, which shall be loaned back to the reorganized company upon emergence. Therefore, upon emergence the Debtors will receive $520 million in cash in exchange for a $550 million note, which includes the Backstop Premium.

The Amended BCA will be terminable by the Company and/or the requisite Backstop Parties upon certain customary events specified therein, including, among others, (1) the termination of the Amended RSA, (2) the mutual written consent of the Company and the requisite Backstop Parties by written notice to the other such Party(ies) or (3) either the Company or the requisite Backstop Parties if the effective date of the plan of reorganization has not occurred on or prior to the date that is ten months after the execution date of the Initial BCA (subject to certain extensions as set forth in the Initial BCA).

NYSE Delisting of our leasing arrangements and may result in variability in our revenue recognition patterns relative to current U.S. GAAP based on the provisions in each of our drilling contracts. With respect to leases whereby we are the lessee, we expect to recognize lease liabilities and offsetting "right of use" assets ranging from approximately $70 million to $90 million. We are currently evaluating the other impacts that Update 2016-02 and Update 2014-09 will have on our consolidated financial statements and related disclosures.Common Stock




Note 2 -    Atwood Merger

On May 29, 2017, we entered into an Agreement and Plan of Merger (the “Merger Agreement”) with Atwood Oceanics, Inc. (“Atwood”) and Echo Merger Sub, LLC, our wholly-owned subsidiary, and on October 6, 2017 (the "Merger Date"), we completed our acquisition of Atwood pursuant to the Merger Agreement (the “Merger”). Atwood’s financial results will be included in our consolidated results beginning on the Merger Date.

The Merger is expected to strengthen our position as the leader in offshore drilling across a wide range of water depths around the world. The Merger significantly enhances the capabilities of our rig fleet and improves our ability to meet future customer demand with the highest-specification assets.

Consideration

As a result of the Merger, Atwood shareholders received 1.60 Ensco Class A Ordinary shares for each shareChapter 11 Cases and in accordance with Section 802.01D of Atwood common stock, representing a valuethe NYSE Listed Company Manual, on August 19, 2020, we were notified by the NYSE of $9.33 per shareits determination to indefinitely suspend trading of Atwood common stock 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. Total consideration delivered in the Merger consisted of 134.1 millionCompany’s Class A ordinary shares with an aggregate valueand to commence proceedings to delist the Company’s Class A ordinary shares from the NYSE. Our Class A ordinary shares were delisted from the NYSE effective September 14, 2020.

Effective August 19, 2020, the Company’s Class A ordinary shares commenced trading on the OTC Pink Open Market under the symbol “VALPQ."

Going Concern

The condensed consolidated financial statements have been prepared on a going concern basis of $782.0 million.

Assets Acquiredaccounting, which contemplates continuity of operations, realization of assets and Liabilities Assumed
Assets acquiredsatisfaction of liabilities and liabilities assumedcommitments in the Merger will be recorded at their estimated fair values asnormal course of business.

For the remaining duration of the Merger 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. We have not finalized the fair values of assets acquiredChapter 11 Cases, our operations and liabilities assumed; therefore, the fair value estimates set forth belowour ability to develop and execute our business plan are subject to adjustment during a degree of risk and uncertainty associated with the Chapter 11 Cases. The outcome of the Chapter 11 Cases is dependent upon factors that are outside of our control, including actions of the Bankruptcy Court and our creditors. Although the Company expects to emerge from chapter 11 imminently, there
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can be no assurance that we will consummate a plan of reorganization as contemplated by the Amended RSA or complete another plan of reorganization with respect to the Chapter 11 Cases, and as such, there is substantial doubt about our ability to continue as a going concern. Further, we have concluded that management’s plans do not alleviate the substantial doubt about our ability to continue as a going concern brought about by the significant risks and uncertainties related to our liquidity and Chapter 11 Cases for a period of one year measurement period subsequentafter the date that the financial statements are issued.

The condensed consolidated financial statements do not include any adjustments relating to the Merger Date. The estimated fair valuesrecoverability and classification of certain assetsrecorded asset amounts or the amounts and classification of liabilities including inventory, long-lived assets and contingencies require judgments and assumptions that increasemight result from the likelihood that adjustments may be made to these estimates during the measurement period, and thoseoutcome of this uncertainty. These adjustments could be material.


Reorganization Items

Expenditures, gains and losses that are realized or incurred by the Debtors as of or subsequent to the Petition Date and as a direct result of the Chapter 11 Cases are reported as Reorganization items, net in our Condensed Consolidated Statement of Operations for the three months ended March 31, 2021. These costs include legal and other professional advisory service fees pertaining to the Chapter 11 Cases and contract items related to rejecting certain operating leases ("Contract items").

The provisional amounts for assets acquiredfollowing table provides information about reorganization items incurred during the three months ended March 31, 2021 (in millions):
Three Months Ended March 31, 2021
Professional fees$47.8 
Contract items3.9 
Reorganization items (fees)51.7 
Contract items.5 
Reorganization items (non-cash).5 
Total reorganization items, net$52.2 
Reorganization items (fees) unpaid$35.8 
Reorganization items (fees) paid$15.9 

Liabilities Subject to Compromise

The Debtors' pre-petition unsecured senior notes and liabilities assumed are based on preliminary estimates of their fair valuesrelated unpaid accrued interest as of the MergerPetition Date have been classified as Liabilities Subject to Compromise on our Condensed Consolidated Balance Sheets. The liabilities are reported at the amounts expected to be allowed as claims by the Bankruptcy Court.











15

Liabilities subject to compromise at March 31, 2021 and December 31, 2020 consist of the following (in millions):

6.875% Senior notes due 2020$122.9 
4.70% Senior notes due 2021100.7 
4.875% Senior notes due 2022620.8 
3.00% Exchangeable senior notes due 2024849.5 
4.50% Senior notes due 2024303.4 
4.75% Senior notes due 2024318.6 
8.00% Senior notes due 2024292.3 
5.20% Senior notes due 2025333.7 
7.375% Senior notes due 2025360.8 
7.75% Senior notes due 20261,000.0 
7.20% Debentures due 2027112.1 
7.875% Senior notes due 2040300.0 
5.40% Senior notes due 2042400.0 
5.75% Senior notes due 20441,000.5 
5.85% Senior notes due 2044400.0 
Amounts drawn under revolving credit facility581.0 
Accrued Interest on Senior Notes, Exchangeable Senior Notes, Debentures and Revolving Credit Facility203.5 
Rig holding costs(1)
13.9 
Total liabilities subject to compromise$7,313.7 

(1)    Represents the holding costs incurred to maintain VALARIS DS-13 and VALARIS DS-14 in the shipyard until the delivery date.

The principal balance on our unsecured senior notes and the amount of outstanding borrowings on our revolving credit facility have been reclassified from Debt to Liabilities Subject to Compromise on our Condensed Consolidated Balance Sheet as of March 31, 2021 and December 31, 2020. Accrued interest on our unsecured senior notes and revolving credit facility was also reclassified from Other Current Liabilities to Liabilities Subject to Compromise on our Condensed Consolidated Balance Sheet as of March 31, 2021 and December 31, 2020.
The contractual interest expense on our unsecured senior notes and revolving credit facility is in excess of recorded interest expense by $100.3 million for the three months ended March 31, 2021. This excess contractual interest is not included as interest expense on the Condensed Consolidated Statements of Operations for the three months ended March 31, 2021, as the Company has discontinued accruing interest on the unsecured senior notes and revolving credit facility subsequent to the Petition Date. We discontinued making interest payments on our unsecured senior notes beginning in June 2020.
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Debtor Financial Statements
Unaudited condensed consolidated financial statements of the Debtors are set forth below. These financial statements exclude the financial statements of the non-debtor subsidiaries. Transactions and balances of receivables and payables between the Debtors have been eliminated in consolidation. Amounts payable to or receivable from the non-Debtor subsidiaries are reported in the unaudited Condensed Combined Balance Sheet of the Debtors.

VALARIS PLC AND CERTAIN SUBSIDIARIES PARTY TO THE BANKRUPTCY CASES
(DEBTOR-IN-POSSESSION)
CONDENSED COMBINED STATEMENTS OF OPERATIONS
(Unaudited)
(In millions)
Three Months Ended
March 31,
2021
OPERATING REVENUES
Operating revenues$250.1 
Operating revenues from non-debtor subsidiaries20.6 
Total operating revenues270.7 
OPERATING EXPENSES
Contract drilling (exclusive of depreciation)207.7 
Loss on impairment756.5 
Depreciation113.9 
General and administrative24.2 
Operating expenses for non-debtor subsidiaries17.7 
Total operating expenses1,120.0 
EQUITY IN EARNINGS OF ARO1.9 
OPERATING LOSS(847.4)
OTHER INCOME (EXPENSE)
Interest income2.6 
Interest income for non-debtor subsidiaries58.6 
Interest expense, net(1.3)
Interest expense for non-debtor subsidiaries(66.4)
Reorganization items, net(52.2)
Other, net18.9 
(39.8)
LOSS BEFORE INCOME TAXES(887.2)
EQUITY IN LOSSES OF SUBSIDIARIES(12.5)
PROVISION FOR INCOME TAXES15.0 
NET LOSS$(914.7)
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VALARIS PLC AND CERTAIN SUBSIDIARIES PARTY TO THE BANKRUPTCY CASES
(DEBTOR-IN-POSSESSION)
CONDENSED COMBINED BALANCE SHEET
(In millions)
March 31, 2021December 31, 2020
(Unaudited)
ASSETS
CURRENT ASSETS 
    Cash and cash equivalents$186.2 $228.9 
    Accounts receivable, net389.1 382.5 
Accounts receivable from non-debtor subsidiaries2,804.7 2,812.0 
    Other current assets360.6 377.4 
Total current assets3,740.6 3,800.8 
PROPERTY AND EQUIPMENT, AT COST11,172.8 12,256.1 
    Less accumulated depreciation1,758.8 1,973.8 
       Property and equipment, net9,414.0 10,282.3 
LONG-TERM NOTES RECEIVABLE FROM ARO442.7 442.7 
LONG-TERM NOTES RECEIVABLE FROM NON-DEBTOR SUBSIDIARIES2,205.3 2,205.3 
INVESTMENT IN ARO122.8 120.9 
INVESTMENTS IN NON-DEBTOR SUBSIDIARIES573.4 585.9 
OTHER ASSETS151.9 158.2 
 $16,650.7 $17,596.1 
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES 
Accounts payable - trade$152.1 $149.4 
Accrued liabilities and other235.4 196.2 
Total current liabilities387.5 345.6 
LONG-TERM NOTES PAYABLE TO NON-DEBTOR SUBSIDIARIES2,548.6 2,548.6 
OTHER LIABILITIES531.3 602.3 
Total liabilities not subject to compromise3,467.4 3,496.5 
Liabilities subject to compromise7,313.7 7,313.7 
Total debtors' equity5,869.6 6,785.9 
Total liabilities and debtors' equity$16,650.7 $17,596.1 





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VALARIS PLC AND CERTAIN SUBSIDIARIES PARTY TO THE BANKRUPTCY CASES
(DEBTOR-IN-POSSESSION)
CONDENSED COMBINED STATEMENT OF CASH FLOWS
(Unaudited)
(In millions)
Three Months Ended
March 31,
2021
OPERATING ACTIVITIES
Net loss$(914.7)
Adjustments to reconcile net loss to net cash used in operating activities:
Loss on impairment756.5 
Depreciation expense113.9 
Equity in losses of non-debtor subsidiaries12.5 
Amortization, net(4.6)
Share-based compensation expense3.8 
Equity in earnings of ARO(1.9)
Other.7 
Changes in operating assets and liabilities8.3 
Contributions to pension plans and other post-retirement benefits(22.2)
Changes in advances (to)/from non-debtor subsidiaries7.3 
Net cash used in operating activities(40.4)
INVESTING ACTIVITIES
Additions to property and equipment(6.0)
Net proceeds from disposition of assets3.7 
Net cash used in investing activities(2.3)
DECREASE IN CASH AND CASH EQUIVALENTS(42.7)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD228.9 
CASH AND CASH EQUIVALENTS, END OF PERIOD$186.2 


Note 3 -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 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
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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 ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), and have not disclosed the variable consideration related to our estimated future day rate revenues. The remaining duration of our drilling contracts based on those in place as of March 31, 2021 was between approximately one month and two 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 rig 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.

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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.

Contract assets and liabilities are presented net on our Condensed Consolidated Balance Sheets 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 Condensed Consolidated Balance Sheets.

As of March 31, 2021 and December 31, 2020, we have a contract liability with Saudi Aramco Rowan Offshore Drilling Company ("ARO"), our 50/50 joint venture with Saudi Aramco, representing the difference between the amounts billed under the Lease Agreements and lease revenues earned up to the respective date. See “Note 4 – Equity Method Investment in ARO" for additional details regarding our balances with ARO.

The following table summarizes our contract assets and contract liabilities (in millions):
 March 31, 2021 December 31, 2020
Current contract assets$2.3 $1.4 
Noncurrent contract assets$.3 $.4 
Current contract liabilities (deferred revenue)$53.6 $57.6 
Noncurrent contract liabilities (deferred revenue)$13.9 $14.3 
Changes in contract assets and liabilities during the period are as follows (in millions):
 Contract AssetsContract Liabilities
Balance as of December 31, 2020$1.8 $71.9 
Revenue recognized in advance of right to bill customer2.0 — 
Increase due to cash received— 9.4 
Decrease due to amortization of deferred revenue that was included in the beginning contract liability balance— (13.8)
Decrease due to transfer to receivables during the period(1.2)— 
Balance as of March 31, 2021$2.6 $67.5 
 
Estimated Fair Value
Assets: 
Cash and cash equivalents(1)
$445.4
Accounts receivable(2)
59.4
Other current assets115.9
Property and equipment1,776.1
Other assets26.0
Liabilities: 
Debt(1)
1,305.9
Other liabilities167.1
Net assets acquired949.8
Less: merger consideration(782.0)
Bargain purchase gain$167.8


(1) Upon closing of the Merger, we utilized acquired cash of $445.4 million and cash on hand from the liquidation of short-term investments to repay Atwood's debt and accrued interest of $1.3 billion.

(2) Gross contractual amounts receivable totaled $61.8 million as of the Merger 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 due to depressed offshore drilling company valuations. Market capitalizations across the offshore drilling industry have declined significantly since mid-2014 due to the decline in commodity prices and the related imbalance of supply and demand for drilling rigs. The resulting bargain purchase gain was further driven by the decline in our share price from $6.70 to $5.83 between the last trading day prior to the announcement of the Merger and the Merger Date. The estimated gain will be reflected in other, net, in our consolidated statement of operations during the fourth quarter.

Merger-RelatedDeferred Contract Costs


Merger-relatedCosts incurred for upfront rig mobilizations and certain contract preparations are attributable to our future performance obligation under each respective drilling contract. These costs wereare 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 and consisted of various advisory, legal, accounting, valuation and other professional or consulting fees totaling $3.8 million and $8.0 million during the three-month and nine-month periods ended September 30, 2017, respectively. Theseincurred. Deferred contract costs were included in other current assets and other assets on our Condensed Consolidated Balance Sheets and totaled $11.2 million and $13.8 million as of March 31, 2021 and December 31, 2020, respectively. During the three months ended March 31, 2021 and 2020, amortization of these costs totaled $5.8 million and $11.5 million, respectively.

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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 Condensed Consolidated Balance Sheets and totaled $7.7 million and $8.4 million as of March 31, 2021 and December 31, 2020, respectively. During the three months ended March 31, 2021 and 2020 amortization of these costs totaled $2.6 million and $3.1 million, respectively.

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, with the exception of the contract liabilities related to our Lease Agreements with ARO which would not be contractually payable until the end of the lease term or termination, if sooner. Expected future amortization of our contract liabilities and deferred costs recorded as of March 31, 2021 is set forth in the table below (in millions):
 Remaining 2021202220232024 and Thereafter Total
Amortization of contract liabilities$51.3 $15.6 $.6 $0 $67.5 
Amortization of deferred costs$14.9 $3.5 $.5 $0 $18.9 


Note 4 -Equity Method Investment in ARO

Background
ARO, a company that owns and operates offshore drilling rigs in Saudi Arabia, was formed and commenced operations in 2017 pursuant to the terms of an agreement entered into by Rowan Companies Limited (formerly Rowan Companies plc) ("Rowan") and Saudi Aramco to create a 50/50 joint venture ("Shareholder Agreement"). Pursuant to our completion of the combination with Rowan (the "Rowan Transaction") on April 11, 2019 (the "Transaction Date"), Valaris acquired Rowan's interest in ARO making Valaris a 50% partner. ARO owns 7 jackup rigs, has ordered 2 newbuild jackup rigs, and leases 9 rigs from us through bareboat charter arrangements (the "Lease Agreements") whereby substantially all operating costs are incurred by ARO. As of March 31, 2021, all 9 of the leased rigs were operating under three-year drilling contracts with Saudi Aramco. The seven rigs owned by ARO, previously purchased from Rowan and Saudi Aramco, are currently operating under contracts with Saudi Aramco for an aggregate 15 years provided that the rigs meet the technical and operational requirements of Saudi Aramco.
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 2 newbuild jackups, each with a shipyard price of $176 million, for delivery scheduled in 2022. The joint venture 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. The Company's capital contributions to ARO pursuant to this requirement may require approval of the Bankruptcy Court during the Chapter 11 Cases. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, on a proportionate basis. The joint venture 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
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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 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 remained 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. During the quarter ended June 30, 2020, almost all remaining employees seconded to ARO became employees of ARO. Additionally, our services to ARO under the Transition Services Agreement were completed as of December 31, 2020.

Summarized Financial Information

The operating revenues of ARO presented below reflect revenues earned under drilling contracts with Saudi Aramco for the 7 ARO-owned jackup rigs as well as the rigs leased from us.

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, expensedepending on the function to which the seconded employee's service related. 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):
Three Months Ended
March 31, 2021March 31, 2020
Revenues$122.7 $140.3 
Operating expenses
Contract drilling (exclusive of depreciation)86.3 108.3 
Depreciation16.1 13.0 
General and administrative3.0 8.3 
Operating income17.3 10.7 
Other expense, net4.5 6.6 
Provision for income taxes4.5 .9 
Net income$8.3 $3.2 
March 31, 2021December 31, 2020
Current assets$364.6 $358.6 
Non-current assets789.0 804.0 
Total assets$1,153.6 $1,162.6 
Current liabilities$52.3 $70.8 
Non-current liabilities952.1 950.8 
Total liabilities$1,004.4 $1,021.6 

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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 (losses) of ARO in our condensed consolidated statementsCondensed Consolidated Statements of operations. Upon closingOperations. 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. Our investment in ARO would be assessed for impairment if there were changes in facts and circumstances that indicate a loss in value may have occurred. If a loss were deemed to have occurred and this loss was determined to be other than temporary, the carrying value of our investment would be written down to fair value and an impairment recorded.

We have an equity method investment in ARO that was recorded at its estimated fair value as of the Merger,date we incurred additional Merger-related costsacquired our 50% interest on April 11, 2019 ("Investment Date"). We computed the difference between the fair value of $11.8 million.

Pro Forma ImpactARO's net assets and the carrying value of those net assets in ARO's U.S. GAAP financial statements ("basis differences") on that date. 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. The basis differences are amortized over the remaining life of the Mergerassets or liabilities to which they relate and are recognized as an adjustment to the equity in earnings of ARO in our Condensed 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):

Three Months Ended
March 31,
20212020
50% interest in ARO net income$4.1 $1.6 
Amortization of basis differences(2.2)(7.9)
Equity in earnings (losses) of ARO$1.9 $(6.3)


Related-Party Transactions

Revenues recognized by us related to the Lease Agreements, Transition Services Agreement and Secondment Agreement are as follows (in millions):
Three Months Ended
March 31,
20212020
Lease revenue$16.6 $21.5 
Secondment revenue.8 18.3 
Transition Services revenue0 3.5 
Total revenue from ARO (1)
$17.4 $43.3 
(1)    All of the revenues presented above are included in our Other segment in our segment disclosures. See "Note 14 - Segment Information" for additional information.

Amounts receivable from ARO related to the items above totaled $13.9 million and $21.6 million as of March 31, 2021 and December 31, 2020, respectively, and are included in accounts receivable, net, on our Condensed Consolidated Balance Sheets.

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There were no accounts payable to ARO as of March 31, 2021 or December 31, 2020. We had $34.9 million and $30.9 million of Contract Liabilities related to our Lease Agreements with ARO as of March 31, 2021 and December 31, 2020, respectively.

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 March 31, 2021 and December 31, 2020, the carrying amount of the long-term notes receivable from ARO was $442.7 million. The Shareholders’ Agreement prohibits the sale or transfer of the shareholder note to a third party, except in certain limited circumstances. The notes receivable may be reduced by future Company obligations to the joint venture. Interest is recognized as interest income in our Condensed Consolidated Statements of Operations and totaled $2.6 million and $4.6 million for the three months ended March 31, 2021 and 2020, respectively. As of March 31, 2021, our interest receivable from ARO was $2.6 million, which is included in Accounts receivable, net, on our Condensed Consolidated Balance Sheet. There was no interest receivable from ARO as of December 31, 2020.

Maximum Exposure to Loss

The following unaudited supplemental pro forma results present consolidated information as ifsummarizes the Merger was completed on January 1, 2016. The pro forma results include, among others, (i) the amortization associated with acquired intangibletotal assets and liabilities (ii) a reductionas reflected in depreciation expenseour Condensed Consolidated Balance Sheets 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 and contract assets related to services provided to ARO, partially offset by contract liabilities as well as payables for adjustmentsservices received. Contract liabilities related to property and equipment and (iii) a reductionour Lease Agreements are subject to interest expense resulting fromadjustment during the retirementlease term. The per day bareboat charter amount in the Lease Agreements is subject to adjustment based on actual performance of Atwood's revolving credit facility and 6.50% senior notes due 2020. The pro forma results do not include any potential synergies or non-recurring charges that may result directly from the Merger.respective rig.

March 31, 2021December 31, 2020
Total assets$582.0 $585.2 
Less: total liabilities34.9 30.9 
Maximum exposure to loss$547.1 $554.3 

(in millions, except per share amounts)Three Months Ended
September 30,		 Nine Months Ended
September 30,
 20172016 20172016
Revenues

$561.2
$732.2
 $1,769.8
$2,960.8
Net income

(14.3)136.0
 (24.0)1,196.9
Earnings per share - basic and diluted

(0.03)0.31
 (0.06)2.95



Note 35 -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 (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 March 31, 2021   
Supplemental executive retirement plan assets $18.7 $0 $0 $18.7 
Total financial assets18.7 0 0 18.7 
As of December 31, 2020   
Supplemental executive retirement plan
   assets		$22.6 $0 $0 $22.6 
Total financial assets22.6 0 0 22.6 

25
 
Quoted Prices in Active Markets for Identical Assets
(Level 1)
 
Significant Other Observable Inputs
(Level 2)
 
Significant Unobservable Inputs
(Level 3)
 Total
As of September 30, 2017   
  
  
Supplemental executive retirement plan assets $30.0
 $—
 $—
 $30.0
Derivatives, net—
 6.0
 —
 6.0
Total financial assets$30.0
 $6.0
 $—
 $36.0
        
As of December 31, 2016   
  
  
Supplemental executive retirement plan assets$27.7
 $—
 $—
 $27.7
Total financial assets$27.7
 $—
 $—
 $27.7
Derivatives, net $—
 $(8.8) $—
 $(8.8)
Total financial liabilities$—
 $(8.8) $—
 $(8.8)


Supplemental Executive Retirement Plan Assets

Our Valaris supplemental executive retirement plans (the "SERP") are non-qualified plans that provideprovided eligible employees an opportunity to defer a portion of their compensation for use after retirement. The SERP were frozen to the entry of new participants in November 2019 and to future compensation deferrals as of January 1, 2020. Assets held in a rabbi trust maintained for the SERP wereare marketable securities measured at fair value on a recurring basis using Level 1 inputs and were included in other assets, net, on our condensed consolidated balance sheets.Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020. The fair value measurementmeasurements of assets held in the SERP waswere based on quoted market prices.

Derivatives
Our derivatives were measured at fair value on a recurring basis using Level 2 inputs. See "Note 4 - 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 measurement of our derivatives was 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 long-term debt instruments were as follows (in millions):
Subject to Compromise (1)
March 31,
2021		December 31,
2020
Carrying Value  Estimated Fair Value  Carrying Value  Estimated Fair Value  
6.875% Senior notes due 2020$122.9 $20.8 $122.9 $8.6 
4.70% Senior notes due 2021100.7 12.5 100.7 4.5 
4.875% Senior notes due 2022620.8 81.3 620.8 32.9 
3.00% Exchangeable senior notes due 2024(2)
849.5 101.9 849.5 76.5 
4.50% Senior notes due 2024303.4 36.7 303.4 13.7 
4.75% Senior notes due 2024318.6 43.6 318.6 18.8 
8.00% Senior notes due 2024292.3 58.8 292.3 12.9 
5.20% Senior notes due 2025333.7 38.0 333.7 12.7 
7.375% Senior notes due 2025360.8 49.8 360.8 20.9 
7.75% Senior notes due 20261,000.0 111.0 1,000.0 44.0 
7.20% Debentures due 2027112.1 14.2 112.1 5.7 
7.875% Senior notes due 2040300.0 54.0 300.0 21.0 
5.40% Senior notes due 2042400.0 53.2 400.0 23.6 
5.75% Senior notes due 20441,000.5 108.1 1,000.5 38.0 
5.85% Senior notes due 2044400.0 53.2 400.0 26.0 
Amounts borrowed under revolving credit facility(3)
581.0 581.0 581.0 581.0 
Total debt$7,096.3 $1,418.1 $7,096.3 $940.8 
Less : Liabilities Subject to Compromise7,096.3 1,418.1 7,096.3 940.8 
Total long-term debt$0 $0 $0 $0 

(1)     The Commencement of the Chapter 11 Cases on August 19, 2020, constituted an event of default under our Senior Notes and revolving credit facility. Any efforts to enforce payment obligations under the Senior Notes and revolving credit facility, including any rights to require the repurchase by the Company of the 2024 Convertible Notes (as defined below) upon the NYSE delisting of the Class A ordinary shares, are automatically stayed as a result of the filing of the Chapter 11 Cases. The carrying amounts above represent the aggregate principal amount of Senior Notes outstanding as well as outstanding borrowings under our revolving credit facility as of the Petition Date and are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020. We discontinued accruing interest on our indebtedness as of the Petition Date and all accrued interest as of the Petition Date is classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance
26

 September 30,
2017		 December 31,
2016
 Carrying Value   Estimated Fair Value   Carrying Value   Estimated Fair Value  
8.50% Senior notes due 2019$253.7
 $252.3
 $480.2
 $485.0
6.875% Senior notes due 2020480.3
 465.2
 735.9
 727.5
4.70% Senior notes due 2021266.9
 264.6
 674.4
 658.9
3.00% Exchangeable senior notes due 2024(1)
628.2
 726.8
 604.3
 874.7
4.50% Senior notes due 2024619.1
 520.2
 618.6
 536.0
8.00% Senior notes due 2024338.2
 330.2
 —
 —
5.20% Senior notes due 2025663.4
 564.0
 662.8
 582.3
7.20% Debentures due 2027149.2
 139.2
 149.2
 138.7
7.875% Senior notes due 2040377.1
 256.6
 378.3
 270.6
5.75% Senior notes due 2044971.6
 731.9
 970.8
 728.0
Total$4,747.7
 $4,251.0
 $5,274.5
 $5,001.7
Sheets as of March 31, 2021 and December 31, 2020. There are no remaining unamortized debt discounts, premiums or issuance costs related to our Senior Notes or revolving credit facility, including the amounts related to the 2024 Convertible Notes discussed below as all were written off to reorganization items as of the Petition Date in 2020. See "Note 2 - Chapter 11 Proceedings and Ability to Continue as a Going Concern" for additional information.


(1)
Our exchangeable senior notes due 2024 (the "2024 Convertible Notes") were issued with a conversion feature. The 2024 Convertible Notes were separated into their liability and equity components on our condensed 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 amount of the 2024 Convertible Notes was $833.5 million and $830.1 million as of September 30, 2017 and December 31, 2016, respectively.

(2)    Our 3% exchangeable senior notes due 2024 (the "2024 Convertible Notes") are exchangeable into cash, our Class A ordinary shares or a combination thereof. The 2024 Convertible Notes were separated, at issuance, into their liability and equity components on our Condensed Consolidated Balance Sheet. The equity component was initially recorded to additional paid-in capital and as a debt discount and the discount was being amortized to interest expense over the life of the instrument. As discussed above, the carrying amount at March 31, 2021 and December 31, 2020 represents the aggregate principal amount of these notes as of the Petition Date and are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020. We discontinued accruing interest on these notes as of the Petition Date. The equity component was $220.0 million as of March 31, 2021 and December 31, 2020 and remains in Additional Paid-Capital.

(3)    In addition to the amount borrowed above, we had $26.0 million and $27.0 million in undrawn letters of credit issued under the revolving credit facility as of March 31, 2021 and December 31, 2020, respectively.

While the revolving credit facility has not been terminated, no further borrowings are permitted. As discussed above, the carrying amount at March 31, 2021 and December 31, 2020 represents the outstanding borrowings as of the Petition Date and are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020. We discontinued accruing interest on the revolving credit facility as of the Petition Date.

The estimated fair values of our senior notes and debentures were determined using quoted market prices. The decline in the carrying value of long-term debt instruments from December 31, 2016 to September 30, 2017 is primarily due to the January 2017 debt exchange and debt repurchases as discussed in "Note 7 - Debt."

prices, which are level 1 inputs. The estimated fair values of our cash and cash equivalents, short-term investments, receivables,accounts receivable, notes receivable and trade payables and other liabilities approximated their carrying values as of September 30, 2017March 31, 2021 and December 31, 2016. Our short-term investments2020.

Note 6 -Property and Equipment

    Property and equipment as of March 31, 2021 and December 31, 2020 consisted of the following (in millions):
March 31, 2021December 31, 2020
Drilling rigs and equipment$11,497.2 $12,584.4 
Work-in-progress444.2 446.1 
Other184.5 178.8 
$12,125.9 $13,209.3 

Impairment of Long-Lived Assets

During the first quarter of 2021, we recorded an aggregate pre-tax, non-cash impairment with respect to certain floaters of $756.5 million, which is included in loss on impairment in our Condensed Consolidated Statement of Operations.

During the first quarter of 2020, we recorded an aggregate pre-tax, non-cash impairment with respect to certain floaters, jackups and spare equipment of $2.8 billion, which is included in loss on impairment in our Condensed Consolidated Statement of Operations.
27

Assets held-for-use

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. 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.

During the first quarter of 2021, as a result of challenging market conditions for certain of our floaters, we have revised our near-term operating assumptions which have resulted in a triggering event for purposes of evaluating impairment. We determined that the estimated undiscounted cash flows were not sufficient to recover the carrying values for certain rigs and concluded they were impaired as of March 31, 2021.

Based on the asset impairment analysis performed as of March 31, 2021, we recorded a pre-tax, non-cash loss on impairment in the first quarter for certain floaters totaling $756.5 million. We measured the fair value of these assets to be $26.0 million at the time depositsof impairment by applying either an income approach, using projected discounted cash flows or estimated sales price. These valuations were based on unobservable inputs that require significant judgments for which there is limited information, including, in the case of an income approach, assumptions regarding future day rates, utilization, operating costs and capital requirements. In instances where we applied an income approach, forecasted day rates and utilization took into account current market conditions and our anticipated business outlook.

During the first quarter of 2020, the COVID-19 global pandemic and the response thereto negatively impacted the macro-economic environment and global economy. Global oil demand fell sharply at the same time global oil supply increased as a result of certain oil producers competing for market share which lead to a supply glut. As a consequence, Brent crude oil fell from around $60 per barrel at year-end 2019 to around $20 per barrel as of mid-April 2020. These adverse changes and impacts to our customer's capital expenditure plans in the first quarter resulted in further deterioration in our forecasted day rates and utilization for the remainder of 2020 and beyond. As a result, we concluded that a triggering event had occurred, and we performed a fleet-wide recoverability test. We determined that our estimated undiscounted cash flows were not sufficient to recover the carrying values of certain rigs and concluded such were impaired as of March 31, 2020.

Based on the asset impairment analysis performed as of March 31, 2020, we recorded a pre-tax, non-cash loss on impairment in the first quarter with initial maturitiesrespect to certain floaters, jackups and spare equipment totaling $2.8 billion. We measured the fair value of these assets to be $72.3 million at the time of impairment by applying either an income approach, using projected discounted cash flows or estimated sales price. These valuations were based on unobservable inputs that require significant judgments for which there is limited information, including, in the case of an income approach, assumptions regarding future day rates, utilization, operating costs and capital requirements. In instances where we applied an income approach, forecasted day rates and utilization took into account then current market conditions and our anticipated business outlook at that time, both of which had been impacted by the adverse changes in the business environment observed during the first quarter of 2020.

Assets held-for-sale

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. We continue to focus on our fleet management strategy in light of the composition of our rig fleet. While taking into account certain restrictions on the sales of assets under our DIP Credit Agreement, as part of our strategy, we may act opportunistically from time to time to monetize assets to enhance stakeholder value and improve our liquidity profile, in addition to reducing holding costs by selling or disposing of older, lower-specification or non-core rigs. To this end, we continually assess our rig portfolio and actively work with our rig broker to market certain rigs.

28

On a quarterly basis, we assess whether any rig meets the criteria established for held-for-sale classification on our balance sheet. All rigs classified as held-for-sale are recorded at fair value, less costs to sell. We measure the fair value of our assets held-for-sale by applying a market approach based on unobservable third-party estimated prices that would be received in exchange for the assets in an orderly transaction between market participants or a negotiated sales price. We reassess the fair value of our held-for-sale assets on a quarterly basis and adjust the carrying value, as necessary.

Assets held-for-sale had an aggregate carrying value of $2.3 million and is included in other assets, net, on our Condensed Consolidated Balance Sheet as of December 31, 2020.

Note 7 -Pension and Other Post-retirement Benefits

    We have defined-benefit pension plans and a retiree medical plan that provides post-retirement health and life insurance benefits.

    The components of net periodic pension and retiree medical cost were as follows (in millions):
 Three Months Ended
March 31,
20212020
Service cost (1)
$0 $.6 
Interest cost (2)
5.0 6.5 
Expected return on plan assets(2)
(9.1)(9.5)
Amortization of net loss (2)
0.1 0 
Net periodic pension and retiree medical cost (income)$(4.0)$(2.4)

(1)Included in contract drilling and general and administrative expense in our Condensed Consolidated Statements of Operations.

(2)Included in other, net, in our Condensed Consolidated Statements of Operations.

During the three months ended March 31, 2021, we contributed $22.2 million to our pension and other post-retirement benefit plans, of which $7.0 million and $5.3 million relate to the 2020 and 2019 plan year contributions, respectively, that were deferred under the U. S. Cares Act. Additionally, in March 2021, the American Rescue Plan Act of 2021 ("ARPA-21") was passed. ARPA-21 provides funding relief for U.S. qualified pension plans which should lower pension contribution requirements over the next few years. As a result, we will not make contributions to certain plans for the remainder of 2021. However, we expect to make contributions to certain other plans for the remainder of 2021 of approximately $2.7 million. These amounts represent the minimum contributions we are required to make under relevant statutes. We do not expect to make contributions in excess of three months but less than one year as of each respective balance sheet date.the minimum required amounts.

Note 48 -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 foreign currency forward contractspreviously used derivatives to reduce our exposure to various market risks, primarily foreign currency exchange rate risk.

All
29

The commencement of the Chapter 11 Cases constituted a termination event with respect to the Company’s derivative instruments, which permitted the counterparties of our derivative instruments to terminate their outstanding contracts. The exercise of these termination rights are not stayed under the Bankruptcy Code and the counterparties elected to terminate their outstanding derivatives were recordedwith us in September 2020. As a result, we do not have derivative assets or liabilities on our condensed consolidated balance sheets at fair value. Derivatives subject to legally enforceable master netting agreements were not offset in our condensed consolidated balance sheets. Accounting for the gains and losses resulting from changes in derivative fair value depends on the use of the derivative and whether it qualifies for hedge accounting.  Net assets of $6.0 million and net liabilities of $8.8 million associated with our foreign currency forward contracts were included on our condensed consolidated balance sheetsCondensed Consolidated Balance Sheets as of September 30, 2017March 31, 2021 and December 31, 2016, respectively.  All of our derivatives mature during the next 18 months.  See "Note 3 - Fair Value Measurements" for additional information on the fair value measurement of our derivatives.2020.


Derivatives recorded at fair value on our condensed consolidated balance sheets consisted of the following (in millions):
 Derivative Assets Derivative Liabilities
 September 30,
2017		 December 31,
2016		 September 30,
2017		 December 31,
2016
Derivatives Designated as Hedging Instruments   
  
  
Foreign currency forward contracts - current(1)
$6.4
 $4.1
 $.7
 $11.4
Foreign currency forward contracts - non-current(2)
.7
 .2
 .1
 .8
 7.1
 4.3
 .8
 12.2
        
Derivatives Not Designated as Hedging Instruments   
  
  
Foreign currency forward contracts - current(1)
.8
 .4
 1.1
 1.3
 .8
 .4
 1.1
 1.3
Total$7.9
 $4.7
 $1.9
 $13.5
(1)
Derivative assets and liabilities with maturity dates equal to or less than twelve months from the respective balance sheet date were included in other current assets and accrued liabilities and other, respectively, on our condensed consolidated balance sheets.

(2)
Derivative assets and liabilities with maturity dates greater than twelve months from the respective balance sheet date were included in other assets, net, and other liabilities, respectively, on our condensed consolidated balance sheets.

We utilizepreviously utilized 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 expensesexpense and capital expenditures denominated in various currencies. As of September 30, 2017, we had cash flow hedges outstanding to exchange an aggregate $164.0 million for various foreign currencies, including $74.4 million for British pounds, $33.8 million for Australian dollars, $23.3 million for euros, $20.3 million for Brazilian reals and $12.2 million for other currencies.


Gains and losses, net of tax, on derivatives designated as cash flow hedges included in our condensed consolidated statementsCondensed Consolidated Statements of operationsOperations and comprehensive (loss) incomeloss for the three month periods ended March 31, 2021 and 2020 were as follows (in millions):


Three Months Ended September 30, 2017
Loss Recognized in
Other Comprehensive Loss
 ("OCI") on Derivatives
(Effective Portion)
Gain Reclassified from ("AOCI") into Income (Effective Portion)(1)
2021202020212020
Foreign currency forward contracts(2)
$0 $(12.9)$(5.6)$(.1)
Total$0 $(12.9)$(5.6)$(.1)

(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)During the three months ended March 31, 2021, $5.6 million of gains were reclassified from AOCI into impairment expense in our Condensed Consolidated Statement of Operations in connection with the impairment of certain rigs. During the three months ended March 31, 2020, $0.9 million of losses were reclassified from AOCI into contract drilling expense and 2016$1.0 million of gains were reclassified from AOCI into depreciation expense in our Condensed Consolidated Statement of Operations.

 Gain (Loss) Recognized in Other Comprehensive (Loss) Income (Effective Portion)   
(Loss) Gain Reclassified from Accumulated Other Comprehensive Income ("AOCI") into Income (Effective Portion)(1)
 
Gain Recognized in Income on Derivatives (Ineffective Portion and Amount Excluded from Effectiveness Testing)(2)
 2017 2016 2017 2016 2017 2016
Interest rate lock contracts(3)
$—
 $—
 $(.1) $(.1) $—
 $—
Foreign currency forward contracts(4)
1.7
 —
 .2
 (2.1) .3
 .2
Total$1.7
 $—
 $.1
 $(2.2) $.3
 $.2



Nine Months Ended September 30, 2017 and 2016
 Gain (Loss) Recognized in Other Comprehensive (Loss) Income (Effective Portion)   
Loss Reclassified from AOCI into Income (Effective Portion)(1)
 
(Loss) Gain Recognized in Income on Derivatives (Ineffective Portion and Amount Excluded from Effectiveness Testing)(2)
 2017 2016 2017 2016 2017 2016
Interest rate lock contracts(3)
$—
 $—
 $(.3) $(.2) $—
 $—
Foreign currency forward contracts(5)
7.7
 (.6) (.8) (9.9) (.1) 2.1
Total$7.7
 $(.6) $(1.1) $(10.1) $(.1) $2.1

(1)
Changes in the effective portion of cash flow hedge fair values 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 ineffectiveness and amounts excluded from effectiveness testing were included in other, net, in our condensed consolidated statements of operations.

(3)
Losses on interest rate lock derivatives reclassified from AOCI into income were included in interest expense, net, in our condensed consolidated statements of operations.

(4)
During the three-month period ended September 30, 2017, there were no net amounts reclassified from AOCI into contract drilling expense and $200,000 of gains were reclassified from AOCI into depreciation expense in our condensed consolidated statement of operations. During the three-month period ended September 30, 2016, $2.3 million of losses were reclassified from AOCI into contract drilling expense and $200,000 of gains were reclassified from AOCI into depreciation expense in our condensed consolidated statement of operations.

(5)
During the nine-month period ended September 30, 2017, $1.4 million of losses were reclassified from AOCI into contract drilling expense and $600,000 of gains were reclassified from AOCI into depreciation expense in our condensed consolidated statement of operations. During the nine-month period ended September 30, 2016, $10.5 million of losses were reclassified from AOCI into contract drilling expense and $600,000 of gains were reclassified from AOCI into depreciation expense in our condensed 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. WeHistorically, we have occasionally enterentered into derivatives that hedge the fair value of recognized foreign currency denominated assets or liabilities but dodid not designate such derivatives as hedging instruments. In these situations, a natural hedging relationship generally existsexisted whereby changes in the fair value of the derivatives offset changes in the fair value of the underlying hedged items. AsNet losses of September 30, 2017, we held derivatives not designated as hedging instruments to exchange an aggregate $137.1$0.1 million for various foreign currencies, including $94.4 million for euros, $12.3 million for British pounds, $10.1 million for Brazilian reals, $7.7 million for Australian dollars and $12.6 million for other currencies.
Net gains of $2.7 million and net losses of $400,000 associated with our derivatives not designated as hedging instruments were included in other, net, in our condensed consolidated statementsCondensed Consolidated Statement of operationsOperations for the three-month periods three monthsended September 30, 2017 and 2016, respectively. Net gains of $8.9 million and $500,000 associated with our derivatives not designated as hedging instruments were included in other, net, in our condensed consolidated statements of operations for the nine-month periods ended September 30, 2017 and 2016, respectively. These gains and losses were largely offset by net foreign currency exchange gains and losses during the respective periods.March 31, 2020.


As of September 30, 2017, the estimated amount of net gains associated with derivative instruments, net of tax, that would be reclassified into earnings during the next twelve months totaled $3.3 million.
Note 5 - 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 condensed consolidated balance sheets, and net income attributable to noncontrolling interests is presented separately in our condensed consolidated statements of operations.
(Loss) income from continuing operations attributable to Ensco for the three-month and nine-month periods ended September 30, 2017 and 2016 was as follows (in millions):
30
 Three Months Ended
September 30,		 Nine Months Ended
September 30,
 2017 2016 2017 2016
(Loss) income from continuing operations$(28.0) $88.0
 $(96.7) $858.4
Loss (income) from continuing operations attributable to noncontrolling interests2.8
 (2.0) .5
 (5.4)
(Loss) income from continuing operations attributable to Ensco$(25.2) $86.0
 $(96.2) $853.0

Note 69 - Earnings Per Share
 
We compute basic and diluted earnings per share ("EPS") in accordance with the two-class method. Net (loss) incomeloss attributable to EnscoValaris 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 the three months ended March 31, 2021 and 2020, 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) incomeDuring the three months ended March 31, 2021, loss from continuing operations attributable to EnscoValaris and loss from continuing operations attributable to Valaris shares usedwas $910.0 million. During the three months ended March 31, 2020, loss from continuing operations attributable to Valaris and loss from continuing operations attributable to Valaris shares was $3.0 billion. No amounts were allocated to non-vested share awards in our basic and diluted EPS computations for the three-month and nine-month periods ended September 30, 2017 and 2016 (in millions):either period given that losses are not allocated to non-vested share awards.

 Three Months Ended
September 30,		 Nine Months Ended
September 30,
 2017 2016 2017 2016
(Loss) income from continuing operations attributable to Ensco$(25.2) $86.0
 $(96.2) $853.0
Income from continuing operations allocated to non-vested share awards(1)
(.1) (1.8) (.3) (15.1)
(Loss) income from continuing operations attributable to Ensco shares$(25.3) $84.2
 $(96.5) $837.9

(1)
Losses are not allocated to non-vested share awards. Therefore, only dividends attributable to our non-vested share awards are included in the three-month and nine-month periods ended September 30, 2017.

AntidilutiveAnti-dilutive share awards totaling 1.3 million300,000 and 1.2 million400,000 were excluded from the computation of diluted EPS for the three-monththree months ended March 31, 2021 and nine-month periods ended September 30, 2017 and 2016,2020, respectively. Due to the net loss position, potentially dilutive share awards are excluded from the computation of diluted EPS.


WeUnder the terms of our debt agreement, we have the option to settle our 2024 Convertible Notes in cash, shares or a combination thereof for the aggregate amount due upon conversion. Our intent isHowever, the Commencement of the Chapter 11 Cases on August 19, 2020, constituted an event of default under the 2024 Convertible Notes. Any efforts to settleenforce payment obligations under the principal amount2024 Convertible Notes, including any rights to require the repurchase by the Company 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 excessNYSE delisting of the principal amount.



Class A ordinary shares, are automatically stayed as a result of the filing of the Chapter 11 Cases. 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 three-month or nine-month periodsthree months ended September 30, 2017.March 31, 2021 and 2020.

Note 7 -Debt

Exchange Offers

In January 2017, we completed exchange offers (the "Exchange Offers")Upon emergence from chapter 11, the existing Class A ordinary shares may be exchanged for 7-year warrants to exchange our outstanding 8.50% senior notes due 2019, 6.875% senior notes due 2020 and 4.70% senior notes due 2021 for 8.00% senior notes due 2024 and cash.purchase up to 7% of the New Equity (subject to dilution on account of the management incentive plan contemplated by the Amended RSA). The Exchange Offers resulted in the tenderstrike price of $649.5 million aggregate principal amount of our outstanding senior notes that were settled and exchanged as follows (in millions):

  Aggregate Principal Amount Repurchased 8.00% Senior notes due 2024 Consideration 
Cash Consideration(1)
 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
Total $649.5
 $332.0
 $332.5
 $664.5
(1)
As of December 31, 2016, the aggregate amount of principal repurchased with cash of $332.5 million, along with associated premiums, was classified as current maturities of long-term debt on our condensed consolidated balance sheet.
During the first quarter, we recognizedsuch warrants, if granted, will be set at a net pre-tax loss on the Exchange Offers of $6.2 million, consisting of a loss of $3.5 million that includes the write-off of premiums on tendered debt and $2.7 million of transaction costs.

Open Market Repurchases

During the nine-month period ended September 30, 2017, we repurchased certain of our outstanding senior notes with cash on hand and recognized an insignificant pre-tax gain, net of discounts, premiums and debt issuance costs. The aggregate repurchases were as follows (in millions):
 Aggregate Principal Amount Repurchased 
Aggregate Repurchase Price(1)
8.50% Senior notes due 2019$54.6
 $60.1
6.875% Senior notes due 2020100.1
 105.1
4.70% Senior notes due 202139.4
 39.3
Total$194.1
 $204.5

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

Maturities

Our next debt maturity is $237.6 million during 2019, followed by $450.9 million and $269.7 million during 2020 and 2021, respectively.



Revolving Credit Facility

In October 2017, we amended our revolving credit facility ("Credit Facility") to extend the final maturity date by two years. Previously, our Credit Facility had a borrowing capacity of $2.25 billion through September 2019 that declined to $1.13 billion through September 2020. Subsequentprice per share equal to the amendment,value at which the senior noteholders would receive a 100% recovery on their claims, including accrued interest up to the Petition Date. See “Note 2 - Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional information related to our borrowing capacity is $2.0 billion throughAmended RSA.

Note 10 -Debt

The commencement of the Chapter 11 Cases constituted an event of default under our pre-petition indebtedness. Any efforts to enforce payment obligations under our Debt Instruments and other obligations of the Debtors are automatically stayed as a result of the filing of the Chapter 11 Cases and the holders' rights of enforcement in respect of the Debt Instruments are subject to the applicable provisions of the Bankruptcy Code. See“Note 2 - Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional details regarding the Chapter 11 Cases.

On September 201925, 2020, following approval by the Bankruptcy Court, the Debtors entered into the DIP Credit Agreement, by and declines to $1.2 billion through September 2022. The credit agreement governing our revolving credit facility includes an accordion feature allowing us to increaseamong the commitments expiringCompany and certain wholly owned subsidiaries of the Company, as borrowers, the lenders party thereto and Wilmington Savings Fund Society, FSB, as administrative agent and security trustee, in September 2022 up to an aggregate amount not to exceed $1.5 billion.$500.0 million that will be used to finance, among other things, the ongoing general corporate needs of the Debtors during the course of the Chapter 11 Cases and to pay certain fees, costs and expenses associated with the Chapter 11 Cases. For additional information related to the

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Also in October, Moody's downgradedterms, covenants and restrictions under the DIP Credit Agreement, see“Note 2 - Chapter 11 Proceedings and Ability to Continue as a Going Concern”.

As of March 31, 2021, we had 0 borrowings outstanding against our credit rating from B1 to B2 and Standard & Poor's downgraded our credit rating from BB to B+. DIP Facility.

Senior Notes

The Credit Facility amendment andcommencement of the rating actionsChapter 11 Cases resulted in increasesan event of default under each series of our Senior Notes and all obligations thereunder were accelerated. However, any efforts to enforce payment obligations related to the interest rates applicable toacceleration of our borrowings. The applicable margin rates are 2.50% per annum for Base Rate advances and 3.50% per annum for LIBOR advances. In addition, our quarterly commitment fee increaseddebt have been automatically stayed as a result of the amendment and rating actions to 0.625% per annum on the undrawn portionfiling of the $2.0 billion commitment. 
The Credit Facility requires usChapter 11 Cases. Pursuant to maintain a total debt to total capitalization ratio that is less than or equal to 60% and to provide guarantees from certainthe plan of reorganization contemplated by the Amended RSA, each series 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 debtSenior Notes will be cancelled and liens (subject to customary exceptions, including a permitted lien basket that permits us to raise secured debt up to the lesser of $750 million or 10% of consolidated tangible net worth (as definedholders thereunder will receive the treatment as set forth in the Credit Facility)); entering into certain merger arrangements; selling, leasing, transferring or otherwise disposingplan of all or substantially allreorganization. Accordingly, the $6.5 billion in aggregate principal amount outstanding under the Senior Notes as well as $201.9 million in associated accrued interest as of the Petition Date are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.

In December 2016, Ensco Jersey Finance Limited, a wholly-owned subsidiary of Valaris plc, issued $849.5 million aggregate principal amount of 2024 Convertible Notes in a private offering. The 2024 Convertible Notes are fully and unconditionally guaranteed, on a senior, unsecured basis, by Valaris plc. Under the terms of our assets; makingdebt agreement, we have the option to settle our 2024 Convertible Notes in cash, shares or 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 continue paying a quarterly dividend of $0.01 per share); borrowings, if after giving effect to any such borrowings and the application of the proceedscombination thereof for the aggregate amount of available cash (as defined indue upon conversion. However, the Credit Facility) would exceed $150 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 dayscommencement of the completionChapter 11 Cases on August 19, 2020, constituted an event of default under the 2024 Convertible Notes. Any efforts to enforce payment obligations under the 2024 Convertible Notes, including any rights to require the repurchase by the Company 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 under2024 Convertible Notes upon the Credit Facility.

AsNYSE delisting of September 30, 2017, we were in compliance in all material respects with our covenants under the Credit Facility. We had no amounts outstanding under the Credit Facility as of September 30, 2017 and December 31, 2016.

Our access to credit and capital markets depends on the credit ratings assigned to our debt. 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 may result in higher borrowing costs and require more restrictive terms and covenants, which may further restrict our operations. With a credit rating below investment grade, we have no access to the commercial paper market.
Note 8 -Shareholders' Equity

As a U.K. company governed in part by the Companies Act, we cannot issue new shares (other than in limited circumstances) without being authorized by our shareholders. At our last annual general meeting held on May 22, 2017, our shareholders authorized the allotment of 101.1 million Class A ordinary shares, (or 202.2are automatically stayed as a result of the filing of the Chapter 11 Cases. The aggregate principal amount of 2024 Convertible Notes outstanding as well as associated accrued interest as of the Petition Date are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.
Revolving Credit Facility

As of March 31, 2021, we had $581.0 million of borrowings outstanding under our revolving credit facility and $26.0 million of undrawn letters of credit. The principal and interest under our revolving credit facility became immediately due and payable upon filing of the Chapter 11 Cases, which constituted an event of default under the revolving credit facility. However, the ability of the lenders under the revolving credit facility to exercise remedies in respect of the revolving credit facility was stayed upon commencement of the Chapter 11 Cases. While the revolving credit facility has not been terminated, notwithstanding the $1.6 billion borrowing capacity under the revolving credit facility, no further borrowings under the revolving credit facility are permitted. The outstanding borrowings as well as accrued interest as of the Petition Date are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.


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Note 11 -Shareholders' Equity

Activity in our various shareholders' equity accounts for the three months ended March 31, 2021 and 2020 were as follows (in millions, except per share amounts):
 Shares Par ValueAdditional
Paid-in
Capital		Retained
Earnings (Deficit)		AOCI Treasury
Shares		Non-controlling
Interest
BALANCE, December 31, 2020206.1 $82.6 $8,639.9 $(4,183.8)$(87.9)$(76.2)$(4.3)
Net loss— — — (910.0)— — 2.4 
Shares issued under share-based compensation plans, net— — (.2)— — .2 — 
Net changes in pension and other postretirement benefits— — — — .1 — — 
Share-based compensation cost— — 3.8 — — — — 
Net other comprehensive loss— — — — (5.4)— — 
BALANCE, March 31, 2021206.1 $82.6 $8,643.5 $(5,093.8)$(93.2)$(76.0)$(1.9)
 Shares Par ValueAdditional
Paid-in
Capital		Retained
Earnings (Deficit)		AOCI Treasury
Shares		Non-controlling
Interest
BALANCE, December 31, 2019205.9 $82.5 $8,627.8 $671.7 $6.2 $(77.3)$(1.3)
Net loss— — — (3,006.3)— — (1.4)
Shares issued under share-based compensation plans, net— — (.7)— — .9 — 
Repurchase of shares— — — — — (.9)— 
Share-based compensation cost— — 7.8 — — — — 
Net other comprehensive loss— — — — (13.4)— — 
BALANCE, March 31, 2020205.9 $82.5 $8,634.9 $(2,334.6)$(7.2)$(77.3)$(2.7)

Pursuant to the terms contemplated in the Amended RSA, upon emergence from bankruptcy, our existing Class A ordinary shares in connection with an offerwill be frozen and removed from trading. Upon emergence from chapter 11, the existing Class A ordinary shares may be exchanged for 7-year warrants to purchase up to 7% of the New Equity (subject to dilution on account of the management incentive plan contemplated by waythe Amended RSA). The strike price of such warrants, if granted, will be set at a rights issue or other similar issue) forprice per share equal to the value at which the senior noteholders would receive a period100% recovery on their claims, including accrued interest up to the conclusionPetition Date. See “Note 2 - Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional information related to our Amended RSA.

Note 12 -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 2018 annual general meeting (or, if earlier,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. Therefore, we generally incur income tax expense in periods in which we operate at a loss.
Our drilling rigs frequently move from one taxing jurisdiction to another to perform contract drilling services. In some instances, the closemovement of business on August 22, 2018).



On October 5, 2017 in conjunction withdrilling rigs among taxing jurisdictions will involve the approvaltransfer of ownership of the Merger,drilling rigs among our shareholders authorized an increase in our allotment to reflect our expected enlarged share capital immediately following the completion of the Merger.subsidiaries. As a result of frequent changes in the authorization,taxing jurisdictions in which our share allotment increaseddrilling 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 146.1 million Class A ordinary shares (or 292.2 million Class A ordinary sharesanother.
33


Income tax rates and taxation systems in connection with an offer by way of a rights issuethe jurisdictions in which our subsidiaries conduct operations vary and our subsidiaries are frequently subjected to minimum taxation regimes. In some jurisdictions, tax liabilities are based on gross revenues, statutory or negotiated deemed profits or other similar issue).factors, rather than on net income and our subsidiaries are frequently unable to realize tax benefits when they operate at a loss. Accordingly, during periods of declining profitability, our income tax expense may not decline proportionally with income, which could result in higher effective income tax rates. Furthermore, we will continue to incur income tax expense in periods in which we operate at a loss.


In connection with the Merger on October 6, 2017,Historically, we issued 134.1 million Ensco Class A ordinary shares to Atwood shareholders.
Note 9 -Income Taxes
We have historically calculated our provision for income taxes during interim reporting periods by applying the estimated annual effective tax rate for the full fiscal year to pre-tax income or loss, excluding discrete items, for the reporting period. We determined that since small changes in estimated pre-tax income or loss would result in significant changes in ourthe estimated annual effective tax rate, the historical method utilized would not provide a reliable estimate of income taxes for the three-monththree months ended March 31, 2021 and nine-month periods ended September 30, 2017.2020. We used a discrete effective tax rate method to calculate income taxes for the three-monththree months ended March 31, 2021 and nine-month periods ended September 30, 2017.2020. We will continue to evaluate income tax estimates under the historical method in subsequent quarters and employ a discrete effective tax rate method if warranted.


Discrete income tax expense for the three-month periodthree months ended September 30, 2017March 31, 2021 was $3.2$20.3 million and resultedwas primarily from a rig sale and resolutions of prior year tax matters. Discrete income tax expense for the nine-month period ended September 30, 2017 was $13.0 million and resulted primarily from the Exchange Offers and debt repurchases, rig sales, a restructuring transaction, settlement of a previously disclosed legal contingency, the effective settlement of a liabilityattributable to changes in liabilities for unrecognized tax benefits associated with a tax positionpositions taken in prior years and other resolutions of prior year tax matters.

Our consolidated effectiveyears. Discrete income tax ratebenefit for the three-month and nine-month periodsthree months ended September 30, 2016, excluding the impact of discrete tax items,March 31, 2020 was 6.0% and 21.9%, respectively. Net discrete income tax benefits for the three-month and nine-month periods ended September 30, 2016 of $6.0$164.4 million and $1.6 million, respectively, werewas primarily attributable to a restructuring transaction, implementation of the gain on debt extinguishment,U.S. Cares Act, changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and other resolutions of prior year tax matters. DiscreteExcluding the aforementioned discrete tax items, income tax expense for the nine-monththree months ended March 31, 2021 and 2020 was $11.4 million and $12.4 million, respectively.

Unrecognized Tax Benefits

During 2019, the Luxembourg tax authorities issued aggregate tax assessments totaling approximately €142.0 million (approximately $166.6 million converted using the current period-end exchange rates) related to tax years 2014, 2015 and 2016 for several of Rowan's Luxembourg subsidiaries. We recorded €93.0 million (approximately $109.1 million converted using the current period-end exchange rates) in purchase accounting related to these assessments. During the first quarter of 2020, in connection with the administrative appeals process, the tax authority withdrew assessments of €142.0 million (approximately $166.6 million converted using the current period-end exchange rates), accepting the associated tax returns as previously filed. Accordingly, we de-recognized previously accrued liabilities for uncertain tax positions and net wealth taxes of €79.0 million (approximately $92.7 million converted using the current period-end exchange rates) and €2.0 million (approximately $2.3 million converted using the current period-end exchange rates), respectively. The de-recognition of amounts related to these assessments was recognized as a tax benefit during the three-month period ended September 30, 2016 also resulted from restructuring transactions involvingMarch 31, 2020 and is included in changes in operating assets and liabilities on the Condensed Consolidated Statement of Cash Flows for the three months ended March 31, 2020.

During 2019, the Australian tax authorities issued aggregate tax assessments totaling approximately A$101 million (approximately $76.7 million converted at current period-end exchange rates) plus interest related to the examination of certain of our subsidiaries.
Note 10 -     Contingencies

Brazil Internal Investigation

Pride International LLC, formerly Pride International, Inc. (“Pride”),tax returns for the years 2011 through 2016. During the third quarter of 2019, we made a company we acquired in 2011, commenced drilling operations in Brazil in 2001. In 2008, Pride entered into a drilling services agreement with Petrobras (the "DSA") for ENSCO DS-5, a drillship ordered from Samsung Heavy Industries, a shipyard in South Korea ("SHI"). Beginning in 2006, Pride conducted periodic compliance reviews of its business with Petrobras, and, after the acquisition of Pride, Ensco conducted similar compliance reviews.

We commenced a compliance review in early 2015 after media reports were released regarding ongoing investigations of various kickback and bribery schemes in Brazil involving Petrobras. While conducting our compliance review, we became aware of an internal audit report by Petrobras alleging irregularities in relationA$42 million payment (approximately $29 million at then-current exchange rates) to the DSA. Upon learningAustralian tax authorities to litigate the assessment. We have a $18.0 million liability for unrecognized tax benefits relating to these assessments as of March 31, 2021. We believe our tax returns are materially correct as filed, and we are vigorously contesting these assessments. Although the Petrobras internal audit report,outcome of such assessments and related administrative proceedings cannot be predicted with certainty, we do not expect these matters to have a material adverse effect on our Audit Committee appointed independent counsel to leadfinancial position, operating results and cash flows.

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Note 13 -Contingencies

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. In February 2020, the rig resumed operations. Indonesian authorities initiated an investigation into the alleged irregularities. Further, in Juneevent and July 2015, we voluntarilyhave contacted the SECcustomer, us and the U.S. Department of Justice ("DOJ"), respectively, to advise them of this matter and of our Audit Committee’s investigation. Independent counsel, under the direction of our Audit Committee, has substantially completed its investigation by reviewing and analyzing available documents and correspondence and interviewing current and former


employeesother parties involved in drilling the DSA negotiations and the negotiation of the ENSCO DS-5 construction contract with SHI (the "DS-5 Construction Contract").

To date, our Audit Committee has found no credible evidence that Pride or Ensco or any of their current or former employees were aware of or involved in any wrongdoing, and our Audit Committee has found no credible evidence linking Ensco or Pride to any illegal acts committed by our former marketing consultant who provided services to Pride and Ensco in connection with the DSA. Independent counsel has continued to provide the SEC and DOJ with updates throughout the investigation, including detailed briefings regarding its investigation and findings. We entered into a one-year tolling agreement with the DOJ that expired in December 2016. We extended our tolling agreement with the SEC for 12 months until March 2018.

Subsequent to initiating our Audit Committee investigation, Brazilian court documents connected to the prosecution of former Petrobras directors and employees as well as certain other third parties, including our former marketing consultant, referenced the alleged irregularities cited in the Petrobras internal audit report. Our former marketing consultant has entered into a plea agreement with the Brazilian authorities. On January 10, 2016, Brazilian authorities filed an indictment against a former Petrobras director. This indictment states that the former Petrobras director received bribes paid out of proceeds from a brokerage agreement entered into for purposes of intermediating a drillship construction contract between SHI and Pride, which we believe to be the DS-5 Construction Contract. The parties to the brokerage agreement were a company affiliated with a person acting on behalf of the former Petrobras director, a company affiliated with our former marketing consultant, and SHI. The indictment alleges that amounts paid by SHI under the brokerage agreement ultimately were used to pay bribes to the former Petrobras director. The indictment does not state that Pride or Ensco or any of their current or former employees were involved in the bribery scheme or had any knowledge of the bribery scheme.

On January 4, 2016, we received a notice from Petrobras declaring the DSA void effective immediately. Petrobras’ notice alleges that our former marketing consultant both received and procured improper payments from SHI for employees of Petrobras and that Pride had knowledge of this activity and assisted in the procurement of and/or facilitated these improper payments. We disagree with Petrobras’ allegations. See "DSA Dispute" below for additional information.

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 SHI and Pride in relation to the DSA.  The Brazilian authorities requested information regarding our compliance program and the findings of our internal investigations. We are cooperating with the Office of the Attorney General and have provided documents in response to their request.Indonesian authorities. We cannot predict the scope or ultimate outcome of this procedure or whether any other 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. If the SECIndonesian authorities determine that we violated local laws in connection with this matter, we could be subject to penalties including environmental or DOJother liabilities, which may have a material adverse impact on us.

ARO Change of Control Purchase Right

Under the Shareholders’ Agreement, a shareholder is required to provide notice to the other shareholders if it determines that violationsit will undergo a change of control (“Shareholder Change of Control”). After giving notice of such Shareholder Change of Control, the receiving shareholder has the option to purchase all (but not less than all) of the FCPAinterests in ARO of the shareholder undergoing the Shareholder Change of Control for 60 days (subject to certain adjustments if the notice is not delivered on a Business Day) at fair market value. The Company delivered a notice of Shareholder Change of Control to Saudi Aramco on March 12, 2021 and Saudi Aramco’s purchase right in connection therewith will expire under the terms of the Shareholders’ Agreement on May 12, 2021.

ARO Funding Obligations

Valaris and Saudi Aramco have occurred, 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 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 if any governmental authority determinesfunds available from third-party debt financing. ARO paid a 25% down payment from cash on hand for each of the newbuilds ordered in January 2020. 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. The Company's capital contributions to ARO pursuant to this requirement may require approval of the Bankruptcy Court during the Chapter 11 Cases. 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 have violated applicable anti-bribery laws, they could seek civil and criminal sanctions, including monetary penalties, against us, as well as changesare named defendants or parties in certain other lawsuits, claims or proceedings incidental to our business practices and compliance programs,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 of whichliability 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.

35

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 March 31, 2021 totaled $116.6 million and are issued under facilities provided by various banks and other financial institutions. Obligations under these letters of credit are not normally called, as we typically comply with the underlying performance requirement. As of March 31, 2021, we had collateral deposits in the amount of $12.7 million with respect to these agreements.

Note 14 -Segment Information
Our business consists of 4 operating segments: (1) Floaters, which includes our drillships and semisubmersible rigs, (2) Jackups, (3) ARO and (4) Other, which consists of management services on rigs owned by third-parties and the activities associated with our arrangements with ARO under the Rig Lease Agreements, the Secondment Agreement and the Transition Services Agreement. Floaters, Jackups and ARO are also reportable segments.

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." 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. We measure segment assets as property and equipment.

The full operating results included below for ARO 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 - Equity Method Investment in ARO" for additional information on ARO and related arrangements.

Segment information for the three months ended March 31, 2021 and 2020 is presented below (in millions):

Three Months Ended March 31, 2021
FloatersJackupsAROOtherReconciling ItemsConsolidated Total
Revenues$97.3 $172.6 $122.7 $37.2 $(122.7)$307.1 
Operating expenses
Contract drilling (exclusive of depreciation)98.9 135.4 86.3 17.9 (86.3)252.2 
Loss on impairment756.5 0 0 0 0 756.5 
Depreciation56.2 52.4 16.1 11.3 (13.9)122.1 
General and administrative0 0 3.0 0 21.3 24.3 
Equity in earnings of ARO0 0 0 0 1.9 1.9 
Operating income (loss)$(814.3)$(15.2)$17.3 $8.0 $(41.9)$(846.1)
Property and equipment, net$5,685.4 $3,778.9 $729.2 $566.3 $(675.9)$10,083.9 
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Three Months Ended March 31, 2020
FloatersJackupsAROOtherReconciling ItemsConsolidated Total
Revenues$179.6 $212.8 $140.3 $64.2 $(140.3)$456.6 
Operating expenses
Contract drilling (exclusive of depreciation)213.9 226.1 108.3 36.0 (108.3)476.0 
Loss on impairment2,554.3 253.9 0 0 0 2,808.2 
Depreciation89.4 58.5 13.0 11.1 (7.5)164.5 
General and administrative0 0 8.3 0 45.1 53.4 
Equity in (losses) of ARO0 0 0 0 (6.3)(6.3)
Operating income (loss)$(2,678.0)$(325.7)$10.7 $17.1 $(75.9)$(3,051.8)
Property and equipment, net$7,442.5 $4,036.0 $740.6 $610.9 $(672.8)$12,157.2 

Information about Geographic Areas

    As of March 31, 2021, the geographic distribution of our and ARO's drilling rigs was as follows:
FloatersJackupsOtherTotal ValarisARO
North & South America560110
Europe & the Mediterranean7160230
Middle East & Africa289197
Asia & Pacific Rim26080
Total16369617

We provide management services on 2 rigs owned by third-parties not included in the table above.

We are a party to contracts for the construction of 2 drillships in South Korea, VALARIS DS-13 and VALARIS DS-14, that are not included in the table above.

ARO has ordered 2 newbuild jackups which are under construction in the Middle East that are not included in the table above.

Note 15 -Supplemental Financial Information

Condensed Consolidated Balance Sheet Information

Accounts receivable, net, consisted of the following (in millions):
March 31,
2021		December 31,
2020
Trade$258.3 $260.1 
Income tax receivable189.8 190.6 
Other18.0 14.7 
 466.1 465.4 
Allowance for doubtful accounts(16.3)(16.2)
 $449.8 $449.2 

37

Other current assets consisted of the following (in millions):
March 31,
2021		December 31,
2020
Materials and supplies$269.7 $279.4 
Prepaid taxes39.2 32.9 
Prepaid expenses28.8 43.4 
Deferred costs15.4 17.4 
Other30.4 24.8 
 $383.5 $397.9 
Other assets consisted of the following (in millions):
March 31,
2021		December 31,
2020
Tax receivables$66.3 $66.8 
Right-of-use assets39.0 35.8 
Deferred tax assets22.7 21.9 
Supplemental executive retirement plan assets18.7 22.6 
Other25.8 29.1 
$172.5 $176.2 
Accrued liabilities and other consisted of the following (in millions):
March 31,
2021		December 31,
2020
Personnel costs$88.4 $95.6 
Income and other taxes payable57.6 50.8 
Deferred revenue53.6 57.6 
Customer payable36.8 — 
Lease liabilities18.8 15.7 
Other35.4 30.7 
 $290.6 $250.4 
Other liabilities consisted of the following (in millions):
March 31,
2021		December 31,
2020
Unrecognized tax benefits (inclusive of interest and penalties)$290.2 $286.1 
Pension and other post-retirement benefits270.2 296.6 
Intangible liabilities50.1 50.4 
Lease liabilities21.1 21.6 
Supplemental executive retirement plan liabilities19.0 22.9 
Deferred tax liabilities15.7 13.7 
Deferred revenue13.9 14.3 
Personnel costs13.6 11.8 
Customer payable— 35.5 
Other10.8 9.5 
 $704.6 $762.4 
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Accumulated other comprehensive income (loss) consisted of the following (in millions):
March 31,
2021		December 31,
2020
Pension and other post-retirement benefits$(98.1)$(98.2)
Currency translation adjustment6.6 6.5 
Derivative instruments0 5.6 
Other(1.7)(1.8)
$(93.2)$(87.9)

Condensed Consolidated Statement of Operations Information

Other, net, for the three months ended March 31, 2021 and 2020 (in millions):
Three Months Ended
March 31,
20212020
Currency translation adjustments$16.6 $3.8 
Net periodic pension (cost) income, excluding service cost4.0 3.0 
Other income (expense).5 (6.3)
$21.1 $0.5 

Concentration of Risk

We are exposed to credit risk relating to our receivables from customers and our cash and cash equivalents. 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.

Consolidated revenues by customer for the three months ended March 31, 2021 and 2020 were as follows:
Three Months Ended
March 31,
20212020
BP(1)
15 %7 %
Saudi Aramco(2)
8 %10 %
Total(3)
0 %16 %
Other77 %67 %
100 %100 %

(1)During the three months ended March 31, 2021, 43% of the revenues provided by BP were attributable to our Floaters segment, 15% of the revenues were attributable to our Jackups segment, and the remaining were attributable to our managed rigs.

During the three months ended March 31, 2020, 24% of the revenues provided by BP were attributable to our Jackups segment, 12% of the revenues were attributable to our Floaters segment and the remaining were attributable to our managed rigs.

(2)During the three months ended March 31, 2021 and 2020, all Saudi Aramco revenues were attributable to our Jackups segment.

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(3)During the three months ended March 31, 2020, 89% of revenues provided by Total were attributable to the Floaters segment and the remaining were attributable to the Jackups segment.

Consolidated revenues by region for the three months ended March 31, 2021 and 2020 were as follows:
Three Months Ended
March 31,
20212020
U.S. Gulf of Mexico(1)
$56.8 $78.7 
United Kingdom(2)
56.1 52.5 
Norway(2)
54.0 41.0 
Saudi Arabia(3)
41.6 83.9 
Mexico(4)
38.2 16.0 
Angola(5)
19.7 61.5 
Other40.7 123.0 
$307.1 $456.6 

(1)During the three months ended March 31, 2021, 65% of the revenues earned in the U.S. Gulf of Mexico were attributable to our Floaters segment. The remaining revenues were primarily attributable to our managed rigs. During the three months ended March 31, 2020, 57% of the revenues earned in the U.S. Gulf of Mexico were attributable to our Floaters segment, 16% were attributable to our Jackups segment and the remaining revenues were attributable to our managed rigs.

(2)During the three months ended March 31, 2021 and 2020, all revenues earned in the United Kingdom and Norway were attributable to our Jackups segment.

(3)During the three months ended March 31, 2021, 57% of the revenues earned in Saudi Arabia, were attributable to our Jackups segment. The remaining revenues were attributable to our Other segment and related to our rigs leased to ARO and our Secondment Agreement.

During the three months ended March 31, 2020, 53% of the revenues earned in Saudi Arabia were attributable to our Jackups segment. The remaining revenues were attributable to our Other segment and related to our rigs leased to ARO and certain revenues related to our Secondment Agreement and Transition Services Agreement.

(4)During the three months ended March 31, 2021, 56% of the revenues earned in Mexico were attributable to our Floaters segment. The remaining revenues were attributable to our Jackups segment. During the three months ended March 31, 2020, 90% of the revenues earned in Mexico were attributable to our Floaters segment. The remaining revenues were attributable to our Jackups segment.

(5)During the three months ended March 31, 2021, all of the revenues earned in Angola were attributable to our Floaters segment. During the three months ended March 31, 2020, 82% of the revenues earned in Angola were attributable to our Floaters segment, and the remaining revenues were attributable to our Jackups segment.


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Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations
Management's Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the accompanying unaudited condensed consolidated financial statements as of March 31, 2021 and for the three months ended March 31, 2021 and 2020 included elsewhere herein and with our annual report on Form 10-K for the year ended December 31, 2020. The following discussion and analysis contains forward-looking statements that involve risks and uncertainties. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of certain factors, including those set forth under “Risk Factors” in Item 1A of our annual report and elsewhere in this quarterly report. See “Forward-Looking Statements.”

EXECUTIVE SUMMARY

Our Business

We are a leading provider of offshore contract drilling services to the international oil and gas industry. Following the sale of a jackup in April, we currently own an offshore drilling rig fleet of 60 rigs, with drilling operations in almost every major offshore market across five continents. Our rig fleet includes 11 drillships, four dynamically positioned semisubmersible rigs, one moored semisubmersible rig, 44 jackup rigs and a 50% equity interest in ARO, our 50/50 joint venture with Saudi Aramco, which owns an additional seven rigs. We operate the world's largest fleet, including one of the newest ultra-deepwater fleets in the industry and a leading premium jackup fleet.

Chapter 11 Proceedings and Ability to Continue as a Going Concern

On August 19, 2020 (the “Petition Date”), the Debtors filed voluntary petitions for reorganization under chapter 11 of the Bankruptcy Code in the Bankruptcy Court. As part of the chapter 11 cases under the caption In re Valaris plc, et al., Case No. 20-34114 (MI) (the “Chapter 11 Cases”), the Debtors were granted “first-day” relief which enabled the Company to continue operating without interruption or disruption to its relationships with its customers and vendors or its high-quality service delivery. In particular, employee pay and benefits are expected to continue without interruption.

On August 18, 2020, the Debtors entered into the Original RSA with the Consenting Noteholders. On February 5, 2021, the Debtors entered into the Amended RSA with the Consenting Lenders and Consenting Noteholders, which contemplates that the Company will implement the restructuring through the Chapter 11 Cases pursuant to a plan of reorganization and the various related transactions set forth in or contemplated by the Amended RSA. Holders of 100% of the total commitments outstanding under our revolving credit facility and holders of approximately 72% of the aggregate amount of our Senior Notes outstanding are party to the Amended RSA. On March 3, 2021, the Bankruptcy Court confirmed the Debtors' chapter 11 plan of reorganization. Although the Company expects to emerge from chapter 11 imminently, there can be no assurance that we will consummate a plan of reorganization as contemplated by the Amended RSA or complete another plan of reorganization with respect to the Chapter 11 Cases.

See“Note 2 – Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional details regarding the Chapter 11 Cases and related items, the Original RSA and Amended RSA and our ability to continue as a going concern.

Our Industry

Operating results in the offshore contract drilling industry are highly cyclical and are directly related to the demand for 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
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somewhat between regions, significant variations betweenmostregions are generally of a short-term nature due to rig mobility.

As we entered 2020, we expected the volatility that began with the oil price decline in 2014 to continue over the near-term with the expectation that long-term oil prices would remain at levels sufficient to support a continued gradual recovery in the demand for offshore drilling services. We were focused on opportunities to put our rigs to work, manage liquidity, extend our financial runway, and reduce debt as we sought to navigate the extended market downturn and improve our balance sheet. Recognizing our ability to maintain a sufficient level of liquidity to meet our financial obligations depended upon our future performance, which is subject to general economic conditions, industry cycles and financial, business and other factors affecting our operations, many of which are beyond our control, we had significant financial condition. Althoughflexibility within our internal investigation is substantially complete, we cannot predict whether any additional allegations will be madecapital structure to support our liability management efforts. However, starting in early 2020, the COVID-19 pandemic and the response thereto negatively impacted the macro-economic environment and global economy. Global oil demand fell sharply at the same time global oil supply increased as a result of certain oil producers competing for market share, leading to a supply glut. As a consequence, the price of Brent crude oil fell from around $60 per barrel at year-end 2019 to around $20 per barrel in mid-April 2020.In response to dramatically reduced oil price expectations, our customers reviewed, and in most cases lowered significantly, their capital expenditure plans in light of revised pricing expectations. This caused our customers, primarily in the second and third quarters of 2020, to cancel or whether any additional facts relevantshorten the duration of many of our 2020 drilling contracts, cancel future drilling programs and seek pricing and other contract concessions which led to material operating losses and liquidity constraints for us.

In 2020, the combined effects of the global COVID-19 pandemic, the significant decline in the demand for oil and the substantial surplus in the supply of oil resulted in significantly reduced demand and day rates for offshore drilling provided by the Company and increased uncertainty regarding long-term market conditions. These events had a significant adverse impact on our current and expected liquidity position and financial runway and led to the investigationfiling of the Chapter 11 Cases.

While we had pursued a variety of cost-cutting measures such as reductions in corporate overhead and discretionary expenditures, reductions in capital expenditures and an increased focus on operational efficiencies, we determined that based on our significant level of indebtedness and the circumstances described above that a comprehensive restructuring of our indebtedness was needed to improve our financial position. As more fully described in “Note 2– Chapter 11 Proceedings and Ability to Continue as a Going Concern", the Company will be uncoveredundergo a financial restructuring that is intended to reduce debt levels substantially, support continued operations during the coursecurrent lower demand environment and provide a robust financial platform to take advantage of market recovery over the long-term. For additional information related to drilling rig supply and demand, see "Business Environment" below.

At the beginning of 2021, Brent crude oil prices have climbed back to pre-COVID-19 pandemic levels, to approximately $62 per barrel in April 2021, and we have observed a slight increase in customer tendering activity for both floaters and jackups beginning in the latter part of 2020. However, the global recovery from the COVID-19 pandemic remains uneven, and there is still a significant amount of uncertainty around the sustainability of the investigationimprovement in oil prices to support a recovery in demand for offshore drilling services.

Additionally, the full impact that the pandemic and what impact those allegations and additional factsthe decline in oil prices will have on our results of operations, financial condition, liquidity and cash flows is uncertain due to numerous factors, including the timing or conclusionsduration and severity of the investigation. Our Audit Committee will examine any such additional allegationsoutbreak, the continued development, availability and additional factseffectiveness of the ongoing vaccine rollout, the general resumption of global economic activity along with the injection of substantial government monetary and fiscal stimulus and the circumstances surrounding them.sustainability of the improvements in oil prices and demand in the face of market volatility. To date, the COVID-19 pandemic has resulted in only limited operational downtime. Our rigs have had to shut down operations while crews are tested and incremental sanitation protocols are implemented and while crew changes have been restricted as replacement crews are quarantined. We continue to incur additional personnel, housing and logistics costs in order to mitigate the potential impacts of COVID-19 to our operations. In limited instances, we have been reimbursed for these costs by our customers. Our operations and business may be

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DSA Disputesubject to further economic disruptions as a result of the spread of COVID-19 among our workforce, the extension or imposition of further public health measures affecting supply chain and logistics, and the impact of the pandemic on key customers, suppliers, and other counterparties. There can be no assurance that these, or other issues caused by the COVID-19 pandemic, will not materially affect our ability to operate our rigs in the future.


We expect that these challenges will continue for drilling contractors as customers wait to gain additional clarity on the sustainability of improved commodity pricing. We believe the current market and macro-economic conditions will continue to create a challenging contracting environment through 2021, into 2022 and potentially beyond.

Other Chapter 11 Financial Disclosures

Reorganization Items

Expenditures, gains and losses that are realized or incurred by the Debtors as of or subsequent to the Petition Date and as a direct result of the Chapter 11 Cases are reported as Reorganization items, net in our Condensed Consolidated Statement of Operations for the three months ended March 31, 2021. These costs include legal and other professional advisory service fees pertaining to the Chapter 11 Cases and contract items related to rejecting certain operating leases ("Contract items").

The following table provides information about reorganization items incurred during the three months ended March 31, 2021 (in millions):
Three Months Ended March 31, 2021
Professional fees$47.8 
Contract items3.9 
Reorganization items (fees)51.7 
Contract items0.5 
Reorganization items (non-cash)0.5 
Total reorganization items, net$52.2 
Reorganization items (fees) unpaid$35.8 
Reorganization items (fees) paid$15.9 

Liabilities Subject to Compromise

The Debtors' pre-petition unsecured senior notes and related unpaid accrued interest as of the Petition Date have been classified as Liabilities Subject to Compromise on our Condensed Consolidated Balance Sheets. The liabilities are reported at the amounts expected to be allowed as claims by the Bankruptcy Court.


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Liabilities subject to compromise at March 31, 2021 and December 31, 2020consist of the following (in millions):
6.875% Senior notes due 2020$122.9 
4.70% Senior notes due 2021100.7 
4.875% Senior notes due 2022620.8 
3.00% Exchangeable senior notes due 2024849.5 
4.50% Senior notes due 2024303.4 
4.75% Senior notes due 2024318.6 
8.00% Senior notes due 2024292.3 
5.20% Senior notes due 2025333.7 
7.375% Senior notes due 2025360.8 
7.75% Senior notes due 20261,000.0 
7.20% Debentures due 2027112.1 
7.875% Senior notes due 2040300.0 
5.40% Senior notes due 2042400.0 
5.75% Senior notes due 20441,000.5 
5.85% Senior notes due 2044400.0 
Amounts drawn under revolving credit facility581.0 
Accrued Interest on Senior Notes, Exchangeable Senior Notes, Debentures and Revolving Credit Facility203.5 
Rig holding costs(1)
13.9 
Total liabilities subject to compromise$7,313.7 

(1)    Represents the holding costs incurred to maintain VALARIS DS-13 and VALARIS DS-14 in the shipyard until the delivery date.

Backlog

Our backlog was $1.2 billion as of both March 31, 2021 and December 31, 2020. Our backlog excludes ARO's backlog but includes backlog from our rigs leased to ARO at the contractual rates. Contract rates with ARO are subject to adjustment resulting from the shareholder agreement. See "Note 4- Equity Method Investment in ARO" for additional information. Our backlog additions from new contract awards and contract extensions during the three months ended March 31, 2021, were largely offset by revenues realized and customer concessions.

As described above,revenues are realized and if we experience customer contract cancellations, we may experience declines in backlog, which would result in a decline in revenues and operating cash flows over the near-term. Contract backlog was adjusted for drilling contracts signed or terminated after each respective balance sheet date but prior to filing each quarterly and annual report on JanuaryApril 28, 2021 and March 2, 2021, respectively.

ARO backlog, excluding backlog on rigs leased from us, was $869.5 million and $84.2 million as of March 31, 2021 and December 31, 2020, respectively, with the increase in backlog due to contracts awarded to five ARO owned rigs. As a 50/50 joint venture, when ARO realizes revenue from its backlog, 50% of the earnings thereon would be reflected in our results.
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BUSINESS ENVIRONMENT
Floaters

The floater contracting environment remains challenging due to limited demand and excess supply. Floater demand declined materially in March and April 2020, as our customers reduced capital expenditures particularly for capital-intensive, long-lead deepwater projects in the wake of oil price declines from around $60 per barrel at year-end 2019 to around $20 per barrel in mid-April 2020. This caused our customers, primarily in the second and third quarters of 2020, to cancel or delay drilling programs, to terminate drilling contracts and to request contract concessions. We have observed a slight increase in customer tendering activity for floaters that commenced in the latter part of 2020. However, the global recovery from the COVID-19 pandemic remains uneven, and there is still a significant amount of uncertainty around the sustainability of the improvement in oil prices to support a recovery in demand for offshore drilling services.

Our backlog for our floater segment was $340.5 million and $205.7 million as of March 31, 2021 and December 31, 2020, respectively. The increase in our backlog was due to the addition of backlog from new contract awards and contract extensions, partially offset by revenues realized. Contract backlog was adjusted for drilling contracts signed or terminated after each respective balance sheet date but prior to filing each quarterly and annual report on April 28, 2021 and March 2, 2021, respectively.
Utilization for our floaters was 29% during the first quarter compared to 26% in the fourth quarter of 2020. Average day rates were approximately $198,000 during the first quarter compared to approximately $206,000 in the fourth quarter of 2020.
There are approximately 21 newbuild drillships and benign environment semisubmersible rigs reported to be under construction, of which four are scheduled to be delivered before the end of 2021. 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.

Drilling contractors have retired approximately 125 benign environment floaters since the beginning of 2014. Nine benign environment floaters older than 20 years of age are currently idle, five additional benign environment floaters older than 20 years have contracts that will expire within six months without follow-on work, and there are a further 13 benign environment floaters that have been stacked for more than three years. Operating costs associated with keeping these rigs idle as well as expenditures required to re-certify some of these aging rigs may prove cost prohibitive. Drilling contractors will likely elect to scrap or cold-stack some or all of these rigs. Improvements in demand and/or reductions in supply will be necessary before meaningful increases in utilization and day rates are realized.

Jackups

During 2020, demand for jackups declined in light of increased market uncertainty. This caused our customers, primarily in the second and third quarters of 2020, to cancel or delay drilling programs, to terminate drilling contracts and to request contract concessions. We have observed a slight increase in customer tendering activity for jackups that commenced in the latter part of 2020. However, the global recovery from the COVID-19 pandemic remains uneven, and there is still a significant amount of uncertainty around the sustainability of the improvement in oil prices to support a recovery in demand for offshore drilling services.
Our backlog for our jackup segment was $809.9 million and $859.5 million as of March 31, 2021 and December 31, 2020, respectively. The decrease in our backlog was due to customer concessions and revenues realized, partially offset by the addition of backlog from new contract awards and contract extensions. Contract backlog was adjusted for drilling contracts signed or terminated after each respective balance sheet date but prior to filing each quarterly and annual report on April 28, 2021 and March 2, 2021, respectively.

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Utilization for our jackups was 50% during the first quarter compared to 45% in the fourth quarter of 2020. Average day rates were approximately $95,000 during the first quarter compared to approximately $86,000 in the fourth quarter of 2020.

There are approximately 35 newbuild jackup rigs reported to be under construction, of which 15 are scheduled to be delivered before the end of 2021. 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.

Drilling contractors have retired approximately 130 jackups since the beginning of the downturn. Approximately 90 jackups older than 30 years are idle, 30 jackups that are 30 years or older have contracts expiring within the next six months without follow-on work, and there are a further 14 jackups that have been stacked for more than three years. Expenditures required to re-certify some of 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 for the remainder of 2021. Improvements in demand and/or reductions in supply will be necessary before meaningful increases in utilization and day rates are realized.

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.

We continue to focus on our fleet management strategy in light of the composition of our rig fleet. While taking into account certain restrictions on the sales of assets under our DIP Credit Agreement, as part of our strategy, we may act opportunistically from time to time to monetize assets to enhance stakeholder value and improve our liquidity profile, in addition to reducing holding costs by selling or disposing of older, lower-specification or non-core rigs.

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RESULTS OF OPERATIONS

    The following table summarizes our Condensed Consolidated Results of Operations for the three months ended March 31, 2021 and 2020 (in millions):
Three Months Ended
March 31,
20212020
Revenues$307.1 $456.6 
Operating expenses  
Contract drilling (exclusive of depreciation)252.2 476.0 
Loss on impairment756.5 2,808.2 
Depreciation122.1 164.5 
General and administrative24.3 53.4 
Total operating expenses1,155.1 3,502.1 
Equity in (losses) earnings of ARO1.9 (6.3)
Operating loss(846.1)(3,051.8)
Other income (expense), net(29.8)(107.9)
Provision (benefit) for income taxes31.7 (152.0)
Net loss(907.6)(3,007.7)
Net (income) loss attributable to noncontrolling interests(2.4)1.4 
Net loss attributable to Valaris$(910.0)$(3,006.3)

Overview
Revenues decreased $149.5 million, or 33%, for the three months ended March 31, 2021, as compared to the prior year quarter primarily due to $124.0 million from fewer days under contract across our fleet, $30.8 million from the sale of VALARIS 5004, VALARIS JU-84, VALARIS JU-87 and VALARIS JU-88, which operated in the prior year quarter, and $25.9 million due to lower revenues earned under the Secondment Agreement, Lease Agreements and Transition Services agreement with ARO. This decline was partially offset by a $25.0 million increase in revenue for certain rigs with higher average day rates for the three months ended March 31, 2021 as compared to the prior year quarter.

Contract drilling expense decreased $223.8 million, or 47%, for the three months ended March 31, 2021, as compared to the prior year quarter, primarily due to $108.9 million of lower cost on idle rigs, $24.5 million from the sale of VALARIS 5004, VALARIS 5006, VALARIS 8504, VALARIS DS-3, VALARIS DS-5, VALARIS DS-6, VALARIS JU-84, VALARIS JU-87 and VALARIS JU-88 and reduced cost resulting primarily from spend control efforts. Additionally, there was a decline of $17.5 million related to the Secondment Agreement with ARO as almost all remaining employees seconded became employees of ARO during the second quarter of 2020.
During the first quarter of 2021 and 2020, we recorded non-cash losses on impairment totaling $756.5 million and $2.8 billion, respectively, with respect to certain assets in our fleet. See "Note 6 - Property and Equipment" for additional information.

Depreciation expense decreased $42.4 million, or 26% for the three months ended March 31, 2021, as compared to the prior year quarter, primarily due to lower depreciation expense on certain non-core assets which were impaired in the first and second quarters of 2020, some of which were subsequently sold in 2020.
General and administrative expenses decreased by $29.1 million or 54%, for three months ended March 31, 2021, as compared to the prior year comparative period, primarily due to lower professional fees associated with shareholder activism defense and organizational change initiatives, as well as lower merger integration related costs.
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Other expense, net, decreased $78.1 million for the three months ended March 31, 2021 as compared to the prior year quarter, primarily due to a reduction in interest expense as we discontinued accruing interest on our outstanding debt after the Petition Date, and net foreign currency exchange gains realized in the current period. This decrease was partially offset by reorganization items incurred in the current period directly related to the Chapter 11 Cases.

Rig Counts, Utilization and Average Day Rates
The following table summarizes our and ARO's offshore drilling rigs as of March 31, 2021 and 2020:
 20212020
Floaters(1)
1624
Jackups(2)
3641
Other(3)
99
Held-for-sale(4)
—1
Total Valaris6175
Valaris - Under construction22
ARO(5)
77
ARO - Under construction (6)
22

(1)During the second quarter of 2020, we sold VALARIS 5004. During the third quarter of 2020, we sold VALARIS 8500, VALARIS 8501, VALARIS 8502, VALARIS DS-3, VALARIS DS-5 and VALARIS DS-6. During the fourth quarter of 2020, we sold VALARIS 8504.
(2)During the second quarter of 2020, we sold VALARIS JU-71. In the third quarter of 2020, we sold VALARIS JU-87 and JU-105 and in the fourth quarter of 2020, we sold VALARIS JU-84 and VALARIS JU-88.
(3)This represents the nine rigs leased to ARO through bareboat charter agreements whereby substantially all operating costs are incurred by ARO. All jackup rigs leased to ARO are under three-year contracts with Saudi Aramco.
(4)During the second quarter of 2020, we sold VALARIS JU-70.
(5)This represents the seven jackup rigs owned by ARO which are under long-term contracts with Saudi Aramco.
(6)During 2020, ARO ordered two newbuild jackup rigs scheduled for delivery in 2022.

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The following table summarizes our and ARO's rig utilization and average day rates by reportable segment for the three months ended March 31, 2021 and 2020:
Three Months Ended
March 31,
20212020
Rig Utilization(1)
  
Floaters29 %38 %
Jackups50 %61 %
Other (2)
100 %100 %
Total Valaris54 %59 %
ARO90 %90 %
Average Day Rates(3)
  
Floaters$198,485 $195,541 
Jackups95,043 81,492 
Other (2)
31,647 42,343 
Total Valaris$88,637 $94,784 
ARO$93,199 $108,873 
(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 and excluding suspension periods. 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. During the quarter ending March 31, 2021, our method for calculating rig utilization has been updated to remove the impact of suspension periods. To the extent applicable, comparative period calculations will be retroactively adjusted.

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 management 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, revenues earned during suspension periods and revenues attributable to amortization of drilling contract intangibles, by the aggregate number of contract days, adjusted to exclude contract days associated with certain suspension periods, mobilizations, demobilizations and shipyard contracts. During the quarter ending March 31, 2021, our method for calculating average day rates has been updated to remove the impact of suspension periods. To the extent applicable, comparative period calculations will be retroactively adjusted.

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

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Operating Income by Segment
Our business consists of four operating segments: (1) Floaters, which includes our drillships and semisubmersible rigs, (2) Jackups, (3) ARO and (4) Other, which consists of management services on rigs owned by third-parties and the activities associated with our arrangements with ARO under the Rig Lease Agreements, the Secondment Agreement and the Transition Services Agreement,. Floaters, Jackups and ARO are also reportable segments.
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." 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.
The full operating results included below for ARO 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 2016, Petrobras sent- Equity Method Investment in ARO" for additional information on ARO and related arrangements.
    Segment information for the three months ended March 31, 2021 and 2020 is presented below (in millions):

Three Months Ended March 31, 2021
FloatersJackupsAROOtherReconciling ItemsConsolidated Total
Revenues$97.3 $172.6 $122.7 $37.2 $(122.7)$307.1 
Operating expenses
Contract drilling (exclusive of depreciation)98.9 135.4 86.3 17.9 (86.3)252.2 
Loss on impairment756.5 — — — — 756.5 
Depreciation56.2 52.4 16.111.3 (13.9)122.1 
General and administrative— — 3.0 — 21.3 24.3 
Equity in earnings of ARO— — — — 1.9 1.9 
Operating income (loss)$(814.3)$(15.2)$17.3 $8.0 $(41.9)$(846.1)

Three Months Ended March 31, 2020
FloatersJackupsAROOtherReconciling ItemsConsolidated Total
Revenues$179.6 $212.8 $140.3 $64.2 $(140.3)$456.6 
Operating expenses
Contract drilling (exclusive of depreciation)213.9 226.1 108.3 36.0 (108.3)476.0 
Loss on impairment2,554.3 253.9 — — — 2,808.2 
Depreciation89.4 58.5 13.0 11.1 (7.5)164.5 
General and administrative— — 8.3 — 45.1 53.4 
Equity in losses of ARO— — — — (6.3)(6.3)
Operating income (loss)$(2,678.0)$(325.7)$10.7 $17.1 $(75.9)$(3,051.8)

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Floaters

Floater revenue declined $82.3 million, or 46%, for the three months ended March 31, 2021, as compared to the prior year quarter due to $87.8 million as a noticeresult of fewer days under contract across the floater fleet and $11.0 million from the sale of VALARIS 5004, which operated in the prior year quarter. This decline was partially offset by a $14.6 million increase in revenue for certain rigs with higher average day rates for the three months ended March 31, 2021 as compared to us declaring the DSA void effective immediately, reserving its rightsprior year quarter.

Floater contract drilling expense declined $115.0 million, or 54%, for the three months ended March 31, 2021, as compared to the prior year quarter, primarily due to $63.0 million lower cost on idle rigs, $12.7 million due to the sale of VALARIS 5004, VALARIS 5006, VALARIS 8504, VALARIS DS-3, VALARIS DS-5, and stating its intentionVALARIS DS-6, and reduced costs resulting primarily from spend control efforts.

During the first quarter of 2021 and 2020, we recorded non-cash losses on impairment totaling $756.5 million and $2.6 billion, respectively, with respect to seek any restitutioncertain assets in our Floater segment. See "Note 6 - Property and Equipment" for additional information.
Floater depreciation expense declined for the three months ended March 31, 2021, as compared to the prior year quarter, primarily due to lower depreciation expense on certain non-core assets which were impaired in the first and second quarters of 2020, some of which were subsequently sold in 2020.

Jackups

Jackup revenues declined $40.2 million, or 19%, for the three months ended March 31, 2021, as compared to the prior year quarter, primarily due to $36.2 million as a result of fewer days under contract across the jackup fleet and $19.8 million due to the sale of VALARIS JU-84, VALARIS JU-87 and VALARIS JU-88 which operated in the prior year quarter. This decline was partially offset by a $10.4 million increase in revenue for certain rigs with higher average day rates for the three months ended March 31, 2021 as compared to the prior year quarter.

Jackup contract drilling expense declined $90.7 million, or 40%, for the three months ended March 31, 2021, as compared to the prior year quarter, primarily due to $45.9 million of lower cost on idle rigs and $11.8 million due to the sale of VALARIS JU-84, VALARIS JU-87 and VALARIS JU-88, which operated in the prior year quarter, and reduced costs resulting largely from spend control efforts.
During the first quarter of 2020, we recorded a non-cash loss on impairment of $253.9 million with respect to certain assets in our Jackup segment. See "Note 6 - Property and Equipment" for additional information.

Jackup depreciation expense declined $6.1 million, or 10%, for the three months ended March 31, 2021 as compared to the prior year quarter, primarily due to lower depreciation expense on certain non-core assets which were impaired in the first and second quarters of 2020, some of which were subsequently sold in 2020.

ARO

The operating revenues of ARO reflect revenues earned under drilling contracts with Saudi Aramco for the seven ARO-owned jackup rigs and the nine rigs leased from us.

Contract drilling expenses are 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 itthe seconded employees' services related. General and administrative expenses include costs incurred under the Transition Services Agreement and other administrative costs. However, services under the Transition Services Agreement were completed as of December 31, 2020.

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ARO revenue declined $17.6 million, or 13%, for the three months ended March 31, 2021, as compared to the prior year quarter primarily due to lower day rates, as well as fewer operating days related to certain rigs for which operations were temporarily suspended.

ARO contract drilling expense declined $22.0 million, or 20%, for the three months ended March 31, 2021, as compared to the prior year quarter, due to approximately $15 million in lower costs for repairs and maintenance as well as a reduction in bareboat charter expense for the rigs leased from us.

ARO depreciation expense increased $3.1 million or 24% for the three months ended March 31, 2021, as compared to the prior year quarter, due to capital expenditures.

ARO general and administrative expenses declined $5.3 million, or 64%, for the three months ended March 31, 2021, as compared to the prior year quarter due to a reduction in services received under the Transition Services Agreement which was completed as of December 31, 2020 as well as a reduction in professional fees.

See "Note 4 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information on ARO.

Other

Other revenues declined $27.0 million for the three months ended March 31, 2021, as compared to the prior year quarter, primarily due to lower revenues earned under the Secondment Agreement and Transition Services Agreement with ARO of $17.5 million and $3.5 million, respectively. Additionally, revenues earned under the Lease Agreements with ARO decreased $4.9 million. See "Note 4 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information.

Other contract drilling expenses declined $18.1 million for the three months ended March 31, 2021, as compared to the prior year quarter, primarily due to $17.5 million decrease in cost for services provided to ARO under the Secondment Agreement as almost all remaining employees seconded to ARO became employees of ARO during the second quarter of 2020.

Other Income (Expense)
The following table summarizes other income (expense) for the three months ended March 31, 2021 and 2020 (in millions):
Three Months Ended
March 31,
 20212020
Interest income$2.6 $4.8 
Interest expense, net: 
Interest expense(1.3)(113.9)
Capitalized interest— .7 
 (1.3)(113.2)
Reorganization items, net(52.2)— 
Other, net21.1 .5 
 $(29.8)$(107.9)
Interest income for the three months ended March 31, 2021 decreased as compared to the respective prior year quarter primarily due to lower LIBOR rates earned on our note receivable from ARO.

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Interest expense decreased $111.9 million for the three months ended March 31, 2021, as compared to the prior year quarter, as we did not accrue interest on our outstanding debt or amortize discounts, premiums and debt issuance costs subsequent to the chapter 11 filing totaling $100.3 million and $12.9 million, respectively.

Reorganization items, net of $52.2 million recognized during three months ended March 31, 2021 was related to other net losses and expenses directly related to Chapter 11 Cases, consisting of professional fees of $47.8 million and contract items related to the rejection of certain operating leases of $4.4 million.

    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 gains of $16.6 million were included in other, net, for the three months ended March 31, 2021. These gains were primarily attributable to the Libyan dinar and Euro.

Net foreign currency exchange gains of $3.8 million, inclusive of offsetting fair value derivatives, were included in other, net, for the three months ended March 31, 2020. These gains were primarily attributable to the Euro, Norwegian krone and Nigerian naira.

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 entitled. We disagree with Petrobras’ declaration thatapplicable to gross revenues, statutory or negotiated deemed profits or other bases utilized under local tax laws, rather than to net income. Therefore, we generally incur income tax expense in periods in which we operate at a loss.

Our drilling rigs frequently move from one taxing jurisdiction to another to perform contract drilling services. In some instances, the DSA is void. We believe that Petrobras repudiatedmovement of drilling rigs among taxing jurisdictions will involve the DSA and have therefore acceptedtransfer of ownership of the DSA as terminated on April 8, 2016 (the "Termination Date"). At this time, we cannot reasonably determine


the validity of Petrobras' claim or the range ofdrilling rigs among our potential exposure, if any.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.

Income tax rates and taxation systems in the jurisdictions in which our subsidiaries conduct operations vary and our subsidiaries are frequently subjected to minimum taxation regimes. In some jurisdictions, tax liabilities are based on gross revenues, statutory or negotiated deemed profits or other factors, rather than on net income and our subsidiaries are frequently unable to realize tax benefits when they operate at a loss. Accordingly, during periods of declining profitability, our income tax expense may not decline proportionally with income, which could result in higher effective income tax rates. Furthermore, we will continue to incur income tax expense in periods in which we operate at a loss.

Discrete income tax expense for the three months ended March 31, 2021 was $20.3 million and was primarily attributable to changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years. Discrete income tax benefit for the three months ended March 31, 2020 was $164.4 million and was primarily attributable to a restructuring transaction, implementation of the U.S. Cares Act, changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and other resolutions of prior year tax matters. Excluding the aforementioned discrete tax items, income tax expense for the three months ended March 31, 2021 and 2020 was $11.4 million and $12.4 million, respectively.

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LIQUIDITY AND CAPITAL RESOURCES

Chapter 11 Cases and Effect of Automatic Stay

On August 19, 2020, the Debtors filed voluntary petitions for reorganization under chapter 11 of the Bankruptcy Code in the Bankruptcy Court and subsequently obtained joint administration of the Chapter 11 Cases under the caption In re Valaris plc, et al., Case No. 20-34114 (MI). Any efforts to enforce payment obligations related to the acceleration of our debt have been automatically stayed as a result of the filing of the Chapter 11 Cases, and the creditors’ rights of enforcement are subject to the applicable provisions of the Bankruptcy Code.

On August 18, 2020, the Debtors entered into the original RSA with the Consenting Noteholders. On February 5, 2021, the Debtors entered into the Amended RSA with the Consenting Noteholders and the Consenting Lenders. The Amended RSA contemplates that the Company will implement the restructuring through the Chapter 11 Cases pursuant to a plan of reorganization and the various related transactions set forth in or contemplated by the Amended RSA. The Amended RSA also provides for certain conditions to the obligations of the parties and for termination upon the occurrence of certain events, including without limitation, the failure to achieve certain milestones and certain breaches by the parties under the Amended RSA.

Subject to certain exceptions, under the Bankruptcy Code, the filing of the Chapter 11 Cases automatically enjoined, or stayed, the continuation of most judicial or administrative proceedings or filing of other actions against the Debtors or their property to recover, collect or secure a claim arising prior to the date of the Chapter 11 Cases. Notwithstanding the general applicability of the automatic stay described above, governmental authorities may determine to continue actions brought under their regulatory powers.

On March 3, 2021, the Bankruptcy Court confirmed the Debtors’ chapter 11 plan of reorganization, which incorporated the terms of the restructuring as set forth in the Amended RSA. Although the Company expects to emerge from chapter 11 imminently, there can be no assurance that we will be successful in completing a restructuring or any other similar transaction on the terms set forth in the Amended RSA, on different terms or at all. Among other things, the Amended RSA includes an outside date milestone requiring the Company’s emergence from chapter 11 by no later than June 15, 2021 (subject to a potential 60-day extension pursuant to the terms of the Amended RSA).

The Debtors continue to operate their businesses and manage their properties as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with applicable provisions of the Bankruptcy Code and orders of the Bankruptcy Court. As part of the Chapter 11 Cases, the Debtors were granted “first-day” relief which enabled the Company to continue operating without interruption or disruption to its relationships with its customers and vendors or its high-quality service delivery. In particular, employee pay and benefits are expected to continue without interruption.

In addition, we have obtained a DIP Facility to fund operations during the bankruptcy proceedings. However, for the remaining duration of the Chapter 11 Cases, our operations and our ability to develop and execute our business plan are subject to a degree of risk and uncertainty associated with the Chapter 11 Cases. The outcome of the Chapter 11 Cases is dependent upon factors that are outside of our control, including actions of the Bankruptcy Court and our creditors. Although the Company expects to emerge from chapter 11 imminently, there can be no assurance that we will consummate a plan of reorganization as contemplated by the Amended RSA or complete another plan of reorganization with respect to the Chapter 11 Cases, and as such, there is substantial doubt about our ability to continue as a going concern. Further, we have concluded that management’s plans do not alleviate the substantial doubt about our ability to continue as a going concern brought about by the significant risks and uncertainties related to our liquidity and Chapter 11 Cases for a period of one year after the date that the financial statements are issued.

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Liquidity
Our liquidity position is summarized in the table below (in millions, except ratios):
March 31,
2021		December 31,
2020
Cash and cash equivalents$291.7 $325.8 
Available DIP Facility capacity500.0 500.0 
   Total liquidity$791.7 $825.8 
Working capital$657.6 $746.1 
Current ratio(1)
2.4 2.7 

(1)As a result of our chapter 11 filing, we reclassified $7.3 billion representing the principal balance on our unsecured senior notes, the amount of outstanding borrowings on our revolving credit facility, the accrued interest on our unsecured senior notes and revolving credit facility, and rig holding costs for VALARIS DS-13 and VALARIS DS-14 to “Liabilities Subject to Compromise” as of March 31, 2021 and December 31, 2020. The current ratio calculated above does not reflect our debt and related interest that would otherwise be current but is stayed under our Chapter 11 Cases, nor does it include rig holding costs for VALARIS DS-13 and VALARIS DS-14.

Cash and Debt

As discussed in "Note 2 - Chapter 11 Proceedings and Ability to Continue as a Going Concern" and above, we have filed the Chapter 11 Cases to effect a comprehensive restructuring of our indebtedness.

The commencement of the Chapter 11 Cases on August 19, 2020, constituted an event of default under our Senior Notes and revolving credit facility. Any efforts to enforce payment obligations under the Senior Notes, including any rights to require the repurchase by the Company of the 2024 Convertible Notes upon the NYSE delisting of the Class A ordinary shares, and revolving credit facility are automatically stayed as a result of the filing of the Chapter 11 Cases. The $6.5 billion aggregate principal amount of Senior Notes outstanding as well as $581.0 million outstanding borrowings under our revolving credit facility as of the Petition Date are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.

On September 25, 2020, we entered into the $500.0 million DIP Facility to provide liquidity during the pendency of the Chapter 11 Cases. On February 5, 2021, we entered into an amendment to the Backstop Commitment Agreement, which we expect to provide exit financing in the form of a fully backstopped rights offering to senior noteholders and certain RCF Lenders for $550 million of New Secured Notes. We expect the DIP Facility will provide sufficient liquidity for us during the pendency of the Chapter 11 Cases. Additionally, we expect the exit financing will provide the necessary liquidity to support ongoing operations and working capital needs.

The maturity date of the DIP Credit Agreement is the earliest of (1) August 17, 2021, (2) acceleration of the loans under the DIP Facility and termination of the lenders' commitments under the DIP Facility, (3) the substantial consummation of any plan filed in the Chapter 11 Cases that is confirmed pursuant to an order entered by the Bankruptcy Court and (4) the consummation of a sale of all or substantially all of the assets of the Company and the other Debtors under section 363 of the Bankruptcy Code. Loans under the DIP Credit Agreement accrue interest at a rate of 8.00% per annum, if paid in kind, and at a rate of 7.00% per annum, if paid in cash.

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The DIP Credit Agreement contains a requirement that the Company and any other borrowers provide every four weeks, a rolling 13 week budget to be approved by the required lenders (the “Approved Budget”). The Company and any other borrower that becomes party to the DIP Credit Agreement may not vary from the Approved Budget by more than 15% of the forecasted amounts in any forecast period. The Approved Budget is, subject to certain exceptions and is tested at certain times in accordance with the DIP Credit Agreement in order to measure variances between the actual total cash disbursements (excluding professional fees and certain other items consistent with the initial Approved Budget) and the disbursements budgeted for the applicable period.

As of March 31, 2021, there were no borrowings outstanding under the DIP Credit Agreement. The DIP Credit Agreement does not provide for the issuance of letters of credit but permits occurrence of letters of credit in certain circumstances. Any proceeds of the loans under the DIP Credit Agreement may be used (1) to provide working capital to the borrowers and their subsidiaries and for other general corporate purposes in accordance with the rolling 13 week budget to be approved by the required lenders every four weeks (subject to the Permitted Variance), (2) to pay interest, fees, costs and expenses related to the DIP Facility, (3) to pay fees, costs and expenses of the estate professionals retained for the Chapter 11 Cases as approved by the Bankruptcy Court and as provided for in the Approved Budget (subject to the Permitted Variance), (4) make all permitted payments of costs of administration of the Chapter 11 Cases, (5) pay pre-petition expenses as are consistent with the Approved Budget (subject to the Permitted Variance) and approved by the Bankruptcy Court, (6) to fund the reasonable activities, costs and fees in respect of any insolvency proceedings in the United Kingdom and (7) make other payments permitted by the applicable Approved Budget.

The DIP Credit Agreement contains events of default customary to debtor-in-possession financings, including events related to the Chapter 11 Cases, the occurrence of which could result in the acceleration of the Debtors’ obligation to repay the outstanding indebtedness under the DIP Credit Agreement. The Debtors’ obligations under the DIP Credit Agreement are secured by a security interest in, and lien on, substantially all present and after acquired property (subject to certain exceptions) of the Debtors and are guaranteed by certain of the Company’s subsidiaries, including other Debtors.

The DIP Credit Agreement also contains customary covenants that limit the ability of the Company and its subsidiaries to, among other things, (1) incur additional indebtedness and permit liens to exist on their assets, (2) pay dividends or make certain other restricted payments, (3) sell assets and (4) make certain investments. These covenants are subject to exceptions and qualifications as set forth in the DIP Credit Agreement.

During the three months ended March 31, 2021, our primary uses of cash were $31.7 million used in operating activities and $6.0 million for the enhancement and other improvements of our drilling rigs.

During the three months ended March 31, 2020, our primary source of cash was $328.9 million in net borrowings under our revolving credit facility. Our primary uses of cash for the same period were $204.4 million used in operating activities, $36.3 million for the construction, enhancement and other improvements of our drilling rigs and $9.7 million for the repurchase of outstanding debt on the open market.

Cash Flow and Capital Expenditures
Our cash flow from operating activities and capital expenditures for the three months ended March 31, 2021 and 2020 were as follows (in millions):
20212020
Net cash used in operating activities$(31.7)$(204.4)
Capital expenditures6.0 36.3 
Cash flows used in operating activities declined $172.7 million as compared to the prior year period primarily due to lower interest cost and improved margins.

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The following table summarizes the timing of our remaining current contractual commitments for VALARIS DS-13 and VALARIS DS-14, which were under construction as of March 31, 2021 (in millions):
20212022Thereafter
Total(1)
VALARIS DS-13$83.9 $— $— $83.9 
VALARIS DS-14— 165.0 — 165.0 
$83.9 $165.0 $— $248.9 

(1)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.
As of March 31, 2021, the contractual delivery dates for the VALARIS DS-13 and VALARIS DS-14 were September 30, 2021 and June 30, 2022, respectively. The remaining milestone payments for VALARIS DS-13 and VALARIS DS-14 are included in the table above in the period in which they were contractually owed.

We entered into amended agreements with the shipyard on February 26, 2021 that become effective upon our emergence from bankruptcy. The amendments provide for, among other things, an option construct whereby the Company has the right, but not the obligation, to take delivery of either or both rigs on or before December 31, 2023. Under the amended agreements, the purchase price for the rigs are estimated to be approximately $119.1 million for the VALARIS DS-13 and $218.3 million for the VALARIS DS-14, assuming a December 31, 2023 delivery date. Delivery can be requested any time prior to December 31, 2023 with a downward purchase price adjustment based on predetermined terms. If the Company elects not to purchase the rigs, the Company has no further obligations to the shipyard. The amended agreements remove any Company guarantee.

Financing and Capital Resources

Senior Notes

The commencement of the Chapter 11 Cases resulted in an event of default under each series of our Senior Notes and all obligations thereunder were accelerated. However, any efforts to enforce payment obligations related to the acceleration of our debt have been automatically stayed as a result of the filing of the Chapter 11 Cases. Pursuant to the plan of reorganization contemplated by the Amended RSA, each series of our Senior Notes will be cancelled and the holders thereunder will receive the treatment as set forth in the plan of reorganization. Accordingly, the $6.5 billion in aggregate principal amount outstanding under the Senior Notes as well as $201.9 million in associated accrued interest as of the Petition Date are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020. See“Note 2 – Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional details regarding the Chapter 11 Cases.

In December 2016, Ensco Jersey Finance Limited, a wholly-owned subsidiary of Valaris plc, issued $849.5 million aggregate principal amount of 3% exchangeable senior notes due 2024 (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. Under the terms of our debt agreement, we have the option to settle our 2024 Convertible Notes in cash, shares or a combination thereof for the aggregate amount due upon conversion. However, the commencement of the Chapter 11 Cases on August 19, 2020, constituted an event of default under the 2024 Convertible Notes. Any efforts to enforce payment obligations under the 2024 Convertible Notes, including any rights to require the repurchase by the Company of the 2024 Convertible Notes upon the NYSE delisting of the Class A ordinary shares, are automatically stayed as a result of the filing of the Chapter 11 Cases. The aggregate principal amount of 2024 Convertible Notes outstanding as well as associated accrued interest as of the Petition Date are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and
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December 31, 2020. See“Note 2 – Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional details regarding the Chapter 11 Cases.

Revolving Credit Facility

As of March 31, 2021, we had $581.0 million of borrowings outstanding under our revolving credit facility and $26.0 million of undrawn letters of credit. The principal and interest under our revolving credit facility became immediately due and payable upon filing of the Chapter 11 Cases, which constituted an event of default under the revolving credit facility. However, the ability of the lenders under the revolving credit facility to exercise remedies in respect of the revolving credit facility was stayed upon commencement of the Chapter 11 Cases. While the revolving credit facility has not been terminated, notwithstanding the $1.6 billion borrowing capacity under the revolving credit facility, no further borrowings under the revolving credit facility are permitted. The outstanding borrowings as well as accrued interest as of the Petition Date are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020. See“Note 2 – Chapter 11 Proceedings and Ability to Continue as a Going Concern” for additional details regarding the Chapter 11 Cases.

DIP Facility
We expect cash on hand and the DIP Facility will provide sufficient liquidity for us during the pendency of the Chapter 11 Cases based on current projections of cash flows. Should we experience material variations from our projected cash flows, this could result in us having insufficient liquidity from the DIP Facility and in turn could have a material adverse impact on our financial position, operating results or cash flows.

As of March 31, 2021, there were no borrowings outstanding under the DIP Credit Agreement and we were in compliance with our covenants under the DIP Credit Agreement.

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, which are governed by the laws of Saudi Arabia, earn interest at LIBOR plus two percent and mature during 2027 and 2028. In the event that ARO is unable to repay these notes when they become due, we would require the prior consent of our joint venture partner to enforce ARO’s payment obligations. The notes receivable may be reduced by future Company obligations to the joint venture.

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 - Equity Method Investment in ARO" 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 March 31, 2021 (in millions):
Maturity DatePrincipal Amount
October 2027$265.0 
October 2028177.7 
Total$442.7 

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Other Financing Arrangements

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 and the Board to conclude that a repurchase is in the best interests of Valaris plc taking into account the interests of relevant stakeholders, 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 March 31, 2021, there had been no share repurchases under this program. Our DIP Credit Agreement only permits the repurchase of our shares in certain limited circumstances and the repurchase of shares would likely require approval of the bankruptcy court. We do not currently expect to make repurchases under the program whilst Valaris plc remains subject to chapter 11 bankruptcy proceedings.

Other Commitments
We have other commitments that we are contractually obligated to fulfill with cash under certain circumstances. As of March 31, 2021, we were contingently liable for an aggregate amount of $116.6 million under outstanding letters of credit which 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 March 31, 2021, we had collateral deposits in the amount of $12.7 million with respect to these agreements.

In connection with our 50/50 joint venture with ARO, we have a potential obligation to fund ARO for newbuild jackup rigs. ARO has plans to purchase 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. 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. The Company's capital contributions to ARO pursuant to this requirement may require approval of the Bankruptcy Court during the Chapter 11 Cases. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, on a proportionate basis. See "Note 4 - Equity Method Investment in ARO" for additional information on our joint venture with ARO.

Recent Tax Assessments

During 2019, the Australian tax authorities issued aggregate tax assessments totaling approximately A$101 million (approximately $76.7 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 a $18 million liability for unrecognized tax benefits relating to these assessments as of March 31, 2021. 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 predicted with certainty, we do not expect these matters to have a material adverse effect on our financial position, operating results and cash flows.


CRITICAL ACCOUNTING POLICIES

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 condensed consolidated financial statements and accompanying notes. Our significant accounting policies are included in Note 1 to our audited consolidated financial statements for the year ended December 31, 2020, included in our annual report on Form 10-K filed with the SEC on March 2, 2021. These policies, along with our underlying judgments and assumptions made in their application, have a significant impact on our condensed consolidated financial statements.
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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 property and equipment, income taxes and pension and other post-retirement benefits. For a discussion of the critical accounting policies and estimates that we use in the preparation of our condensed consolidated financial statements, see "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Critical Accounting Policies and Estimates" in Part II of our annual report on Form 10-K for the year ended December 31, 2020. During the three months ended March 31, 2021, there were no material changes to the judgments, assumptions or policies upon which our critical accounting estimates are based.

New Accounting Pronouncements

See Note 1 - Unaudited Condensed Consolidated Financial Statements to our condensed consolidated financial statements included in "Item 1. Financial Statements" for information on new accounting pronouncements.

Item 3.   Quantitative and Qualitative Disclosures About Market Risk
Not applicable.

Item 4.   Controls and Procedures

Evaluation of Disclosure Controls and Procedures – We have established disclosure controls and procedures to ensure that the information required to be disclosed by us in the reports that we file under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms and that such information is accumulated and made known to the officers who certify the Company’s financial reports and to other members of senior management and the Board of Directors as appropriate to allow timely decisions regarding required disclosure.

We have appropriately implemented Financial Accounting Standards Board Accounting Standard Codification Topic No. 852 – Reorganizations (“ASC 852”), during the quarter and have prepared the Condensed Consolidated Financial Statements and disclosures in accordance with ASC 852.

Based on their evaluation as of March 31, 2021, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) are effective.

Changes in Internal Controls – There have been no changes in our internal controls over financial reporting during the fiscal quarter ended March 31, 2021 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
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PART II - OTHER INFORMATION

Item 1.  Legal Proceedings

UMB Bank Lawsuit

On March 19, 2020, UMB Bank, National Association (“UMB”), the purported indenture trustee for four series of Valaris notes, filed a lawsuit in Harris County District Court in Houston, Texas.  The lawsuit was filed against Valaris plc, two legacy Rowan entities, two legacy Ensco entities and the individual directors of the two legacy Rowan entities. The complaint alleges, among other things, breach of fiduciary duty, aiding and abetting breach of fiduciary duty and fraudulent transfer in connection with certain intercompany transactions occurring after completion of the Rowan merger and the Rowan entities’ guarantee of Valaris’ revolving credit facility.  In addition to an unspecified amount of damages, the lawsuit seeks to void and undo all historical transfers of cash or other assets from legacy Rowan entities to Valaris and its other subsidiaries and the internal reorganization transaction. On August 18, 2020, Valaris and certain of its affiliates entered into the Original RSA, including the noteholders that directed UMB to file the lawsuit. Under the Original RSA and the Amended RSA, the lawsuit is stayed by agreement throughout the pendency of the bankruptcy proceeding unless the Original RSA terminates at which point each party reserves its rights to argue whether the case should proceed while in bankruptcy. On August 24, 2020, the parties filed a joint notice staying the case. If the Original RSA terminates and the case in fact proceeds, we are unable to predict the outcome of this matter or estimate the extent to which we may be exposed to any resulting liability. If the chapter 11 Plan as confirmed by the Bankruptcy Court is consummated, the lawsuit will be dismissed with prejudice. 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 howthe ultimate outcome of the proceedings.

Shareholder Class Action

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. The court appointed a lead plaintiff and lead counsel. The case has now been stayed in light of the Valaris plc bankruptcy filing, with the exception that lead plaintiff may file an amended complaint. At this dispute will ultimately be resolved.time, we are unable to predict the outcome of these matters or the extent of any resulting liability.


Environmental Matters
We didare 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 recognize revenue for amounts owed to us under the DSA from the beginning of the fourth quarter of 2015 through the Termination Date, as we concluded that collectabilityexpect final disposition of these amounts was not reasonably assured. Additionally,assessments to have a material adverse effect on our receivables from Petrobras related to the DSA from prior to the fourth quarter of 2015 are fully reserved in our condensed consolidated balance sheet as of September 30, 2017. We have initiated arbitration proceedings in the U.K. against Petrobras seeking payment of all amounts owed to us under the DSA, in addition to any other amounts to which we are entitled,financial position, operating results and intend to vigorously pursue our claims. Petrobras subsequently filed a counterclaim seeking restitution of certain sums paid under the DSA less value received by Petrobras under the DSA. We have also initiated separate arbitration proceedings in the U.K. against SHI for any losses we have incurred in connection with the foregoing. SHI subsequently filed a statement of defense disputing our claim. Therecash flows, there can be no assurance as to howthe ultimate outcome of these arbitration proceedings will ultimately be resolved.assessments. A $440,000 liability related to these matters was included in accrued liabilities and other on our Condensed Consolidated Balance Sheet as of March 31, 2021.

Customer Dispute


A customer filed a lawsuit in Texas federal court against one of our subsidiaries claiming damages based on allegations that our subsidiary breached and was negligent in the performance of a drilling contract during the period beginning in mid-2011 through May 2012. The customer's court documents alleged damages totaling approximately $40 million.During the second quarter, we settled the lawsuit and agreed to pay the customer $9.8 million, which was recognized in contract drilling expense in our condensed consolidated statements of operations for the nine-month period ended September 30, 2017.
61


Atwood Merger

On June 23, 2017, a putative class action captioned Bernard Stern v. Atwood Oceanics, Inc., et al, was filed in the U.S. District Court for the Southern District of Texas against Atwood, Atwood’s directors, Ensco and Merger Sub. The Stern complaint generally alleges that Atwood and the Atwood directors disseminated a false or misleading registration statement on Form S-4 (the “Registration Statement”) on June 16, 2017, which omitted material information regarding the proposed Merger, in violation of Section 14(a) of the Exchange Act. Specifically, the Stern complaint alleges that Atwood and the Atwood directors omitted material information regarding the parties’ financial projections, the analysis performed by Atwood’s financial advisor, Goldman Sachs & Co. LLC (“Goldman Sachs”), in support of its fairness opinion, the timing and nature of communications regarding post-transaction employment of Atwood's directors and officers, potential conflicts of interest of Goldman Sachs, and whether there were further discussions with another potential acquirer of Atwood following the May 30, 2017 announcement of the Merger. The Stern complaint further alleges that the Atwood directors, Ensco and Merger Sub are liable for these violations as “control persons” of Atwood under Section 20(a) of the Exchange Act. With respect to Ensco, the Stern complaint alleges that Ensco had direct supervisory control over the composition of the Registration Statement. The Stern complaint seeks injunctive relief, including to enjoin the Merger, rescissory damages, and an award of attorneys’ fees in addition to other relief.

On June 27, 2017, June 29, 2017 and June 30, 2017, additional putative class actions captioned Joseph Composto v. Atwood Oceanics, Inc., et al, Booth Family Trust v. Atwood Oceanics, Inc., et al and Mary Carter v. Atwood Oceanics, Inc.et al, respectively, were filed in the U.S. District Court for the Southern District of Texas against Atwood and Atwood’s directors. These actions allege violations of Sections 14(a) and 20(a) of the Exchange Act by Atwood and Atwood’s directors similar to those alleged in the Stern complaint; however, neither Ensco plc nor Merger Sub is named as a defendant in these actions. On October 2, 2017, the actions were consolidated and the Stern matter was designated as the lead case. The plaintiffs subsequently voluntarily dismissed the actions.



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 or cash flows.


In the ordinary course of business with customers and others, we have entered into letters of credit and surety bonds 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 and surety bonds outstanding as of September 30, 2017 totaled $83.5 million and were 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 September 30, 2017, we were not required to make collateral deposits with respect to these agreements.
Note 11 -Segment Information
Our business consists of three operating segments: (1) Floaters, which includes our drillships and semisubmersible rigs, (2) Jackups and (3) Other, which consists of management services on rigs owned by third-parties. Our two reportable segments, Floaters and Jackups, provide one service, contract drilling.
Segment information for the three-month and nine-month periods ended 2017 and 2016 is presented below (in millions). 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 and are included in "Reconciling Items." We measure segment assets as property and equipment.

Three Months Ended September 30, 2017
 Floaters Jackups Other Operating Segments Total Reconciling Items Consolidated Total
Revenues$291.9
 $153.1
 $15.2
 $460.2
 $—
 $460.2
Operating expenses           
Contract drilling (exclusive of depreciation)139.1
 132.9
 13.8
 285.8
 —
 285.8
Depreciation72.7
 31.6
 —
 104.3
 3.9
 108.2
General and administrative—
 —
 —
 —
 30.4
 30.4
Operating income (loss)$80.1
 $(11.4) $1.4
 $70.1
 $(34.3) $35.8
Property and equipment, net$8,545.5
 $2,502.4
 $—
 $11,047.9
 $48.5
 $11,096.4



Three Months Ended September 30, 2016
 Floaters Jackups Other Operating Segments Total Reconciling Items Consolidated Total
Revenues$319.3
 $213.8
 $15.1
 $548.2
 $—
 $548.2
Operating expenses           
Contract drilling (exclusive of depreciation)153.7
 133.2
 11.2
 298.1
 —
 298.1
Depreciation72.9
 32.1
 —
 105.0
 4.4
 109.4
General and administrative—
 —
 —
 —
 25.3
 25.3
Operating income$92.7
 $48.5
 $3.9
 $145.1
 $(29.7) $115.4
Property and equipment, net$8,360.4
 $2,537.9
 $—
 $10,898.3
 $61.4
 $10,959.7

Nine Months Ended September 30, 2017
 Floaters Jackups Other Operating Segments Total Reconciling Items Consolidated Total
Revenues$840.7
 $503.8
 $44.3
 $1,388.8
 $—
 $1,388.8
Operating expenses           
Contract drilling (exclusive of depreciation)431.1
 383.8
 40.3
 855.2
 —
 855.2
Depreciation217.5
 95.3
 —
 312.8
 12.5
 325.3
General and administrative—
 —
 —
 —
 86.9
 86.9
Operating income$192.1
 $24.7
 $4.0
 $220.8
 $(99.4) $121.4
Property and equipment, net$8,545.5
 $2,502.4
 $—
 $11,047.9
 $48.5
 $11,096.4

Nine Months Ended September 30, 2016
 Floaters Jackups Other Operating Segments Total Reconciling Items Consolidated Total
Revenues$1,468.3
 $743.0
 $60.5
 $2,271.8
 $—
 $2,271.8
Operating expenses           
Contract drilling (exclusive of depreciation)573.6
 390.0
 48.4
 1,012.0
 —
 1,012.0
Depreciation231.0
 90.8
 —
 321.8
 13.3
 335.1
General and administrative—
 —
 —
 —
 76.1
 76.1
Operating income$663.7
 $262.2
 $12.1
 $938.0
 $(89.4) $848.6
Property and equipment, net$8,360.4
 $2,537.9
 $—
 $10,898.3
 $61.4
 $10,959.7



Information about Geographic Areas

As of September 30, 2017, the geographic distribution of our drilling rigs by reportable segment was as follows:
 Floaters Jackups 
Total(1)
North & South America8 6 14
Europe & Mediterranean4 10 14
Middle East & Africa3 11 14
Asia & Pacific Rim5 5 10
Asia & Pacific Rim (under construction)— 1 1
Held-for-sale1 — 1
Total21 33 54

(1)
We provide management services on two rigs owned by third-parties not included in the table above.

Note 12 -Supplemental Financial Information

Consolidated Balance Sheet Information

Accounts receivable, net, consisted of the following (in millions):
 September 30,
2017		 December 31,
2016
Trade$338.6
 $358.4
Other31.2
 24.5
 369.8
 382.9
Allowance for doubtful accounts(20.8) (21.9)
 $349.0
 $361.0

Other current assets consisted of the following (in millions):
 September 30,
2017		 December 31,
2016
Inventory$219.7
 $225.2
Prepaid taxes35.8
 30.7
Deferred costs31.4
 32.4
Prepaid expenses14.1
 7.9
Other17.3
 19.8
 $318.3
 $316.0
Other assets, net, consisted of the following (in millions):
 September 30,
2017		 December 31,
2016
Deferred tax assets$54.7
 $69.3
Deferred costs30.8
 35.7
Supplemental executive retirement plan assets30.0
 27.7
Prepaid taxes on intercompany transfers of property—
 33.0
Other9.5
 10.2
 $125.0
 $175.9


Accrued liabilities and other consisted of the following (in millions):
 September 30,
2017		 December 31,
2016
Personnel costs$95.2
 $124.0
Deferred revenue88.0
 116.7
Accrued interest70.6
 71.7
Taxes36.9
 40.7
Derivative liabilities1.8
 12.7
Other8.3
 10.8
 $300.8
 $376.6
Other liabilities consisted of the following (in millions):
 September 30,
2017		 December 31,
2016
Unrecognized tax benefits (inclusive of interest and penalties)
$144.2
 $142.9
Deferred revenue65.5
 120.9
Supplemental executive retirement plan liabilities31.2
 28.9
Personnel costs14.9
 13.5
Other23.4
 16.3
 $279.2
 $322.5
Accumulated other comprehensive income consisted of the following (in millions):
 September 30,
2017		 December 31,
2016
Derivative instruments$22.4
 $13.6
Currency translation adjustment7.8
 7.6
Other(1.6) (2.2)
 $28.6
 $19.0

Concentration of Risk

We are exposed to credit risk relating to our receivables from customers, our cash and cash equivalents, our short-term 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 management's expectations. We mitigate our credit risk relating to cash and cash equivalents by focusing on diversification and quality of instruments. Cash equivalents consist of a portfolio of high-grade instruments. Custody of cash and cash equivalents is maintained at several well-capitalized financial institutions, and we monitor the financial condition of those financial institutions.  

We mitigate our credit risk relating to derivative counterparties 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.  See "Note 4 - Derivative Instruments" for additional information on our derivatives.

Consolidated revenues by customer for the three-month and nine-month periods ended September 30, 2017 and 2016 were as follows:

 Three Months Ended
September 30,		 Nine Months Ended
September 30,
 2017 2016 2017 2016
Total(1)
24% 23% 23% 16%
BP (2)
15% 13% 15% 12%
Petrobras(1)
11% 9% 11% 11%
ConocoPhillips(3)
3% 2% 2% 12%
Other47% 53% 49% 49%
 100% 100% 100% 100%

(1)
During the three-month and nine-month periods ended September 30, 2017 and 2016, all revenues were attributable to our Floater segment.

(2)
During the three-month periods ended September 30, 2017 and 2016, 78% and 73% of the revenues provided by BP, respectively, were attributable to our Floaters segment and no revenue was attributable to our Jackups segment. During the nine-month periods ended September 30, 2017 and 2016, 78% and 75% of the revenues provided by BP, respectively, were attributable to our Floaters segment and no revenue was attributable to our Jackups segment.

(3)
During the nine-month period ended September 30, 2016, excluding the impact of the lump-sum termination payment of $185.0 million for ENSCO DS-9, revenues from ConocoPhillips represented 3% of our consolidated revenues.



Consolidated revenues by region for the three-month and nine-month periods ended September 30, 2017 and 2016 were as follows:

 Three Months Ended
September 30,		 Nine Months Ended
September 30,
 2017 2016 2017 2016
Angola(1)
$118.9
 $142.7
 $356.5
 $411.3
Egypt(2)
53.8
 50.5
 160.4
 87.0
Brazil(2)
51.1
 48.6
 147.6
 251.3
United Kingdom(3)
49.1
 60.5
 117.0
 204.0
Australia(4)
48.7
 44.6
 158.6
 169.4
U.S. Gulf of Mexico(5)(6)
34.9
 33.6
 112.2
 498.3
Other103.7
 167.7
 336.5
 650.5
 $460.2
 $548.2
 $1,388.8
 $2,271.8

(1)
During the three-month periods ended September 30, 2017 and 2016, 85% and 87% of the revenues earned in Angola, respectively, were attributable to our Floaters segment. During the nine-month periods ended September 30, 2017 and 2016, 86% and 87% of the revenues earned in Angola, respectively, were attributable to our Floaters segment.

(2)
During the three-month and nine-month periods ended September 30, 2017 and 2016, all revenues were attributable to our Floaters segment.

(3)
During the three-month and nine-month periods ended September 30, 2017 and 2016, all revenues were attributable to our Jackups segment.

(4)
During the three-month and nine-month periods ended September 30, 2017, 92% and 83% of the revenues earned in Australia were attributable to our Floaters segment. For the three-month and nine-month periods ended September 30, 2016, all revenues were attributable to our Floaters segment.

(5)
During the three-month periods ended September 30, 2017 and 2016, 21% and 41% of the revenues earned, respectively, were attributable to our Floaters segment and 35% and 14% of the revenues earned, respectively, were attributable to our Jackups segment. During the nine-month period ended September 30, 2017 and 2016, 24% and 86% of the revenues earned, respectively, were attributable to our Floaters segment and 37% and 5% earned, respectively, were attributable to our Jackups segment.

(6)
Revenue recognized during the nine-month period ended September 30, 2016 related to the U.S. Gulf of Mexico included termination fees totaling $205.0 million as discussed in "Note 1 - Unaudited Condensed Consolidated Financial Statements." ENSCO DS-9 termination revenues were attributed to the U.S. Gulf of Mexico as the related drilling contract was intended for operations in that region.


Note 13 -Guarantee of Registered Securities

In connection with the Pride acquisition, Ensco plc and Pride entered into a supplemental indenture to the indenture dated July 1, 2004 between Pride and New York Mellon, as indenture trustee, providing for, among other matters, the full and unconditional guarantee by Ensco plc of Pride's 8.5% unsecured senior notes due 2019, 6.875% unsecured senior notes due 2020 and 7.875% unsecured senior notes due 2040, which had an aggregate outstanding principal balance of $1.0 billion as of September 30, 2017. The Ensco plc guarantee provides for the unconditional and irrevocable guarantee of the prompt payment, when due, of any amount owed to the note holders.
Ensco plc is also a full and unconditional guarantor of the 7.2% debentures due 2027 issued by ENSCO International Incorporated, a wholly-owned subsidiary of Ensco plc, during 1997, which had an aggregate outstanding principal balance of $150.0 million as of September 30, 2017.
Pride International LLC (formerly Pride International, Inc.) and Ensco International Incorporated are 100% owned subsidiaries of Ensco plc. All guarantees are unsecured obligations of Ensco plc ranking equal in right of payment with all of its existing and future unsecured and unsubordinated indebtedness.
The following tables present the unaudited condensed consolidating statements of operations for the three-month and nine-month periods ended September 30, 2017 and 2016; the unaudited condensed consolidating statements of comprehensive (loss) income for the three-month and nine-month periods ended September 30, 2017 and 2016; the condensed consolidating balance sheets as of September 30, 2017 (unaudited) and December 31, 2016; and the unaudited condensed consolidating statements of cash flows for the nine-month periods ended September 30, 2017 and 2016, in accordance with Rule 3-10 of Regulation S-X.


ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
Three Months Ended September 30, 2017
(In millions)
(Unaudited)

 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
OPERATING REVENUES$13.0
 $47.2
 $—
 $490.1
 $(90.1) $460.2
OPERATING EXPENSES           
Contract drilling (exclusive of depreciation)11.3
 43.0
 —
 321.6
 (90.1) 285.8
Depreciation—
 4.0
 —
 104.2
 —
 108.2
General and administrative10.3
 5.1
 —
 15.0
 —
 30.4
OPERATING (LOSS) INCOME(8.6) (4.9)
—

49.3

—

35.8
OTHER INCOME (EXPENSE), NET3.4
 (28.0) (17.4) (1.0) 2.6
 (40.4)
(LOSS) INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES(5.2) (32.9)
(17.4)
48.3

2.6

(4.6)
INCOME TAX PROVISION—
 11.6
 —
 11.8
 —
 23.4
DISCONTINUED OPERATIONS, NET—
 —
 —
 (.2) —
 (.2)
EQUITY (LOSSES) EARNINGS IN AFFILIATES, NET OF TAX(20.2) 29.9
 23.2
 —
 (32.9) —
NET (LOSS) INCOME(25.4)
(14.6)
5.8

36.3

(30.3)
(28.2)
NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS—
 —
 —
 2.8
 —
 2.8
NET (LOSS) INCOME ATTRIBUTABLE TO ENSCO$(25.4) $(14.6)
$5.8

$39.1

$(30.3)
$(25.4)


ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
Three Months Ended September 30, 2016
(In millions)
(Unaudited)

 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
OPERATING REVENUES$6.7
 $36.1
 $—
 $581.0
 $(75.6) $548.2
OPERATING EXPENSES 
  
  
  
  
 

Contract drilling (exclusive of depreciation)6.7
 36.5
 —
 330.5
 (75.6) 298.1
Depreciation—
 4.2
 —
 105.2
 —
 109.4
General and administrative9.1
 .1
 —
 16.1
 —
 25.3
OPERATING (LOSS) INCOME(9.1)
(4.7)
—

129.2

—

115.4
OTHER INCOME (EXPENSE), NET6.9
 (32.5) (18.9) 7.8
 5.8
 (30.9)
(LOSS) INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES(2.2)
(37.2)
(18.9)
137.0

5.8

84.5
INCOME TAX PROVISION—
 (3.5) (.6) .6
 —
 (3.5)
DISCONTINUED OPERATIONS, NET—
 —
 —
 (.7) —
 (.7)
EQUITY EARNINGS IN AFFILIATES, NET OF TAX87.5
 60.2
 23.2
 —
 (170.9) —
NET INCOME85.3
 26.5

4.9

135.7

(165.1)
87.3
NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS—
 —
 —
 (2.0) —
 (2.0)
NET INCOME ATTRIBUTABLE TO ENSCO$85.3

$26.5

$4.9

$133.7

$(165.1)
$85.3




ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
Nine Months Ended September 30, 2017
(In millions)
(Unaudited)

 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
OPERATING REVENUES$38.5
 $137.1
 $—
 $1,477.3
 $(264.1) $1,388.8
OPERATING EXPENSES           
Contract drilling (exclusive of depreciation)33.7
 126.4
 —
 959.2
 (264.1) 855.2
Depreciation—
 12.5
 —
 312.8
 —
 325.3
General and administrative33.9
 9.4
 —
 43.6
 —
 86.9
OPERATING (LOSS) INCOME(29.1) (11.2) —
 161.7
 —
 121.4
OTHER EXPENSE, NET(10.2) (86.2) (53.0) (13.6) 11.7
 (151.3)
(LOSS) INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES(39.3) (97.4) (53.0) 148.1
 11.7
 (29.9)
INCOME TAX PROVISION—
 30.5
 —
 36.3
 —
 66.8
DISCONTINUED OPERATIONS, NET—
 —
 —
 (.4) —
 (.4)
EQUITY (LOSSES) EARNINGS IN AFFILIATES, NET OF TAX(57.3) 113.5
 69.4
 —
 (125.6) —
NET (LOSS) INCOME(96.6) (14.4) 16.4
 111.4
 (113.9) (97.1)
NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS—
 —
 —
 .5
 —
 .5
NET (LOSS) INCOME ATTRIBUTABLE TO ENSCO$(96.6) $(14.4) $16.4
 $111.9
 $(113.9) $(96.6)



ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
Nine Months Ended September 30, 2016
(In millions)
(Unaudited)

 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
OPERATING REVENUES$21.5
 $108.2
 $—
 $2,361.7
 $(219.6) $2,271.8
OPERATING EXPENSES 
  
  
  
  
  
Contract drilling (exclusive of depreciation)20.6
 108.6
 —
 1,102.4
 (219.6) 1,012.0
Depreciation—
 12.9
 —
 322.2
 —
 335.1
General and administrative25.8
 .2
 —
 50.1
 —
 76.1
OPERATING (LOSS) INCOME(24.9)
(13.5)
—

887.0

—

848.6
OTHER INCOME (EXPENSE), NET145.9
 (39.2) (56.8) (1.2) 65.7
 114.4
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES121.0

(52.7)
(56.8)
885.8

65.7

963.0
INCOME TAX PROVISION—
 11.9
 (.6) 93.3
 —
 104.6
DISCONTINUED OPERATIONS, NET—
 —
 —
 (1.8) —
 (1.8)
EQUITY EARNINGS IN AFFILIATES, NET OF TAX730.2
 113.7
 87.0
 —
 (930.9) —
NET INCOME851.2

49.1

30.8

790.7

(865.2)
856.6
NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS—
 —
 —
 (5.4) —
 (5.4)
NET INCOME ATTRIBUTABLE TO ENSCO$851.2

$49.1

$30.8

$785.3

$(865.2)
$851.2








ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS) INCOME
Three Months Ended September 30, 2017
(In millions)
(Unaudited)

 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
            
NET (LOSS) INCOME$(25.4) $(14.6) $5.8
 $36.3
 $(30.3) $(28.2)
OTHER COMPREHENSIVE INCOME, NET           
Net change in derivative fair value—
 1.7
 —
 —
 —
 1.7
Reclassification of net income on derivative instruments from other comprehensive income into net (loss) income—
 (.1) —
 —
 —
 (.1)
Other—
 —
 —
 .1
 —
 .1
NET OTHER COMPREHENSIVE INCOME—
 1.6

—

.1

—

1.7
COMPREHENSIVE (LOSS) INCOME(25.4) (13.0)
5.8

36.4

(30.3)
(26.5)
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS—
 —
 —
 2.8
 —
 2.8
COMPREHENSIVE (LOSS) INCOME ATTRIBUTABLE TO ENSCO$(25.4) $(13.0)
$5.8

$39.2

$(30.3)
$(23.7)



ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Three Months Ended September 30, 2016
(In millions)
(Unaudited)

 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
            
NET INCOME$85.3
 $26.5
 $4.9
 $135.7
 $(165.1) $87.3
OTHER COMPREHENSIVE INCOME (LOSS), NET          
Net change in derivative fair value—
 —
 —
 —
 —
 —
Reclassification of net losses on derivative instruments from other comprehensive income into net income—
 2.2
 —
 —
 —
 2.2
Other—
 —
 —
 (.5) —
 (.5)
NET OTHER COMPREHENSIVE INCOME (LOSS)—

2.2

—

(.5)
—
 1.7
COMPREHENSIVE INCOME85.3

28.7

4.9

135.2

(165.1) 89.0
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS—
 —
 —
 (2.0) —
 (2.0)
COMPREHENSIVE INCOME ATTRIBUTABLE TO ENSCO$85.3

$28.7

$4.9

$133.2

$(165.1)
$87.0



ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS) INCOME
Nine Months Ended September 30, 2017
(In millions)
(Unaudited)

 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
            
NET (LOSS) INCOME$(96.6) $(14.4) $16.4
 $111.4
 $(113.9) $(97.1)
OTHER COMPREHENSIVE INCOME, NET          
Net change in derivative fair value—
 7.7
 —
 —
 —
 7.7
Reclassification of net losses on derivative instruments from other comprehensive income into net (loss) income—
 1.1
 —
 —
 —
 1.1
Other—
 —
 —
 .8
 

 .8
NET OTHER COMPREHENSIVE INCOME—

8.8

—

.8

—
 9.6
COMPREHENSIVE (LOSS) INCOME(96.6)
(5.6)
16.4

112.2

(113.9) (87.5)
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS—
 —
 —
 .5
 —
 .5
COMPREHENSIVE (LOSS) INCOME ATTRIBUTABLE TO ENSCO$(96.6)
$(5.6)
$16.4

$112.7

$(113.9)
$(87.0)



ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME
Nine Months Ended September 30, 2016
(In millions)
(Unaudited)

 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
            
NET INCOME$851.2
 $49.1
 $30.8
 $790.7
 $(865.2) $856.6
OTHER COMPREHENSIVE INCOME (LOSS), NET          
Net change in derivative fair value—
 (.6) —
 —
 —
 (.6)
Reclassification of net losses on derivative instruments from other comprehensive income into net income—
 10.1
 —
 —
 —
 10.1
Other—
 —
 —
 (.5) —
 (.5)
NET OTHER COMPREHENSIVE INCOME (LOSS)—

9.5

—

(.5)
—

9.0
COMPREHENSIVE INCOME851.2

58.6

30.8

790.2

(865.2)
865.6
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS—
 —
 —
 (5.4) —
 (5.4)
COMPREHENSIVE INCOME ATTRIBUTABLE TO ENSCO$851.2

$58.6

$30.8

$784.8

$(865.2)
$860.2



ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
September 30, 2017
(In millions)
(Unaudited)

  Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
ASSETS 
           
CURRENT ASSETS           
Cash and cash equivalents$516.0
 $—
 $20.5
 $187.9
 $—
 $724.4
Short-term investments1,065.0
 —
 —
 4.8
 —
 1,069.8
Accounts receivable, net 12.2
 .4
 (.1) 336.5
 —
 349.0
Accounts receivable from affiliates410.8
 173.6
 —
 112.2
 (696.6) —
Other.3
 14.8
 —
 303.2
 —
 318.3
Total current assets2,004.3
 188.8

20.4

944.6

(696.6)
2,461.5
PROPERTY AND EQUIPMENT, AT COST1.8
 124.0
 —
 13,366.8
 —
 13,492.6
Less accumulated depreciation1.8
 76.3
 —
 2,318.1
 —
 2,396.2
Property and equipment, net—
 47.7

—

11,048.7

—

11,096.4
DUE FROM AFFILIATES1,977.8
 2,803.9
 321.0
 4,012.7
 (9,115.4) —
INVESTMENTS IN AFFILIATES8,521.4
 3,575.8
 1,130.7
 —
 (13,227.9) —
OTHER ASSETS, NET —
 40.7
 —
 175.5
 (91.2) 125.0
 $12,503.5
 $6,656.9

$1,472.1

$16,181.5

$(23,131.1)
$13,682.9
LIABILITIES AND SHAREHOLDERS' EQUITY 
        
CURRENT LIABILITIES           
Accounts payable and accrued liabilities$54.6
 $42.8
 $13.1
 $378.2
 $—
 $488.7
Accounts payable to affiliates45.0
 171.3
 10.3
 470.0
 (696.6) $—
Total current liabilities99.6
 214.1

23.4

848.2

(696.6)
488.7
DUE TO AFFILIATES 1,396.0
 3,666.9
 930.4
 3,122.1
 (9,115.4) —
LONG-TERM DEBT 2,840.6
 149.2
 1,111.1
 646.8
 —
 4,747.7
OTHER LIABILITIES—
 10.4
 —
 360.0
 (91.2) 279.2
ENSCO SHAREHOLDERS' EQUITY (DEFICIT)8,167.3
 2,616.3
 (592.8) 11,202.3
 (13,227.9) 8,165.2
NONCONTROLLING INTERESTS—
 —
 —
 2.1
 —
 2.1
Total equity (deficit)8,167.3
 2,616.3

(592.8)
11,204.4

(13,227.9)
8,167.3
      $12,503.5
 $6,656.9

$1,472.1

$16,181.5

$(23,131.1)
$13,682.9



ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
December 31, 2016
(In millions)

  Ensco plc ENSCO International Incorporated Pride International LLC Other Non-Guarantor Subsidiaries of Ensco Consolidating Adjustments Total
ASSETS 
           
CURRENT ASSETS           
Cash and cash equivalents$892.6
 $—
 $19.8
 $247.3
 $—
 $1,159.7
Short-term investments1,165.1
 5.5
 —
 272.0
 —
 $1,442.6
Accounts receivable, net 6.8
 —
 —
 354.2
 —
 361.0
Accounts receivable from affiliates486.5
 251.2
 —
 152.2
 (889.9) —
Other.1
 6.8
 —
 309.1
 —
 316.0
Total current assets2,551.1

263.5

19.8

1,334.8

(889.9)
3,279.3
PROPERTY AND EQUIPMENT, AT COST1.8
 121.0
 —
 12,869.7
 —
 12,992.5
Less accumulated depreciation1.8
 63.8
 —
 2,007.6
 —
 2,073.2
Property and equipment, net  —

57.2

—

10,862.1

—

10,919.3
DUE FROM AFFILIATES1,512.2
 4,513.8
 1,978.8
 7,234.4
 (15,239.2) —
INVESTMENTS IN AFFILIATES8,557.7
 3,462.3
 1,061.3
 —
 (13,081.3) —
OTHER ASSETS, NET —
 81.5
 —
 181.1
 (86.7) 175.9
 $12,621.0

$8,378.3

$3,059.9

$19,612.4

$(29,297.1)
$14,374.5
LIABILITIES AND SHAREHOLDERS' EQUITY 
        
CURRENT LIABILITIES           
Accounts payable and accrued liabilities$44.1
 $45.2
 $28.3
 $404.9
 $—
 $522.5
Accounts payable to affiliates38.8
 208.4
 5.9
 636.8
 (889.9) —
Current maturities of long-term debt187.1
 —
 144.8
 —
 —
 331.9
Total current liabilities270.0

253.6

179.0

1,041.7

(889.9)
854.4
DUE TO AFFILIATES 1,375.8
 5,367.6
 2,040.7
 6,455.1
 (15,239.2) —
LONG-TERM DEBT 2,720.2
 149.2
 1,449.5
 623.7
 —
 4,942.6
OTHER LIABILITIES—
 2.9
 —
 406.3
 (86.7) 322.5
ENSCO SHAREHOLDERS' EQUITY (DEFICIT)8,255.0
 2,605.0
 (609.3) 11,081.2
 (13,081.3) 8,250.6
NONCONTROLLING INTERESTS—
 —
 —
 4.4
 —
 4.4
Total equity (deficit)8,255.0
 2,605.0

(609.3)
11,085.6

(13,081.3)
8,255.0
      $12,621.0
 $8,378.3

$3,059.9

$19,612.4

$(29,297.1)
$14,374.5



ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
Nine Months Ended September 30, 2017
(In millions)
(Unaudited)
 Ensco plc ENSCO International Incorporated Pride International LLC Other Non-guarantor Subsidiaries of Ensco Consolidating Adjustments Total
OPERATING ACTIVITIES 
  
  
  
  
  
Net cash (used in) provided by operating activities of continuing operations$(17.3) $(68.4) $(84.9) $390.2
 $—
 $219.6
INVESTING ACTIVITIES           
Maturities of short-term investments1,123.1
 5.5
 —
 284.1
 —
 1,412.7
Purchases of short-term investments(1,023.0) —
 —
 (17.0) —
 (1,040.0)
Additions to property and equipment —
 —
 —
 (474.1) —
 (474.1)
Purchase of affiliate debt(316.3) —
 —
 —
 316.3
 —
Other—
 —
 —
 2.6
 —
 2.6
Net cash used in investing activities of continuing operations (216.2) 5.5

—

(204.4)
316.3

(98.8)
FINANCING ACTIVITIES 
  
  
  
  
  
Reduction of long-term borrowings(220.7) —
 —
 —
 (316.3) (537.0)
Cash dividends paid(9.4) —
 —
 —
 —
 (9.4)
Debt financing costs(5.5) —
 —
 —
 —
 (5.5)
Advances from (to) affiliates95.1
 62.9
 85.6
 (243.6) —
 —
Other(2.6) —
 —
 (1.9) —
 (4.5)
Net cash (used in) provided by financing activities(143.1) 62.9

85.6

(245.5)
(316.3)
(556.4)
Net cash used in discontinued operations—
 —
 —
 (.4) —

(.4)
Effect of exchange rate changes on cash and cash equivalents—
 —
 —
 .7
 —
 .7
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS(376.6) —

.7

(59.4)
—

(435.3)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD892.6
 —
 19.8
 247.3
 —
 1,159.7
CASH AND CASH EQUIVALENTS, END OF PERIOD$516.0
 $—
 $20.5
 $187.9
 $—
 $724.4



ENSCO PLC AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
Nine Months Ended September 30, 2016
(In millions)
(Unaudited)
 Ensco plc ENSCO International Incorporated  Pride International LLC Other Non-guarantor Subsidiaries of Ensco Consolidating Adjustments Total
OPERATING ACTIVITIES 
  
  
  
  
  
Net cash provided by (used in) operating activities of continuing operations$150.4
 $(23.6) $(95.3) $963.3
 $—
 $994.8
INVESTING ACTIVITIES 
  
  
  
  
 

Maturities of short-term investments1,582.0
 —
 —
 —
 —
 1,582.0
Purchases of short-term investments(1,282.0) —
 —
 (422.0) —
 (1,704.0)
Additions to property and equipment —
 —
 —
 (255.5) —
 (255.5)
Purchase of affiliate debt(237.9) —
 —
 —
 237.9
 —
Other—
 —
 —
 7.7
 —
 7.7
Net cash provided by (used in) investing activities of continuing operations  62.1
 —
 —
 (669.8) 237.9
 (369.8)
FINANCING ACTIVITIES 
  
  
  
  
 

Proceeds from equity issuance585.5
 —
 —
 —
 —
 585.5
Reduction of long-term borrowings(862.4) —
 —
 237.9
 (237.9) (862.4)
Cash dividends paid(8.5) —
 —
 —
 —
 (8.5)
Advances from (to) affiliates156.1
 23.6
 114.1
 (293.8) —
 —
Other(2.0) —
 —
 (0.3) —
 (2.3)
Net cash (used in) provided by financing activities(131.3) 23.6
 114.1
 (56.2) (237.9) (287.7)
Net cash provided by discontinued operations—
 —
 —
 7.4
 —
 7.4
Effect of exchange rate changes on cash and cash equivalents—
 —
 —
 (.6) —
 (.6)
NET INCREASE IN CASH AND CASH EQUIVALENTS81.2
 ��
 18.8
 244.1
 —
 344.1
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD94.0
 —
 2.0
 25.3
 —
 121.3
CASH AND CASH EQUIVALENTS, END OF PERIOD$175.2
 $—
 $20.8
 $269.4
 $—
 $465.4




Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations
Management's Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the accompanying unaudited consolidated financial statements as of September 30, 2017 and for the three-month and nine-month periods ended September 30, 2017 and 2016 included elsewhere herein and with our annual report on Form 10-K for the year ended December 31, 2016. The following discussion and analysis contains forward-looking statements that involve risks and uncertainties. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of certain factors, including those set forth under “Risk Factors” in Item 1A of our annual report and elsewhere in this quarterly report. See “Forward-Looking Statements.”

EXECUTIVE SUMMARY

Our Business

We are one of the leading providers of offshore contract drilling services to the international oil and gas industry. On October 6, 2017, we acquired Atwood Oceanics, Inc. ("Atwood") to further strengthen our position as a leader in offshore drilling across a wide range of water depths around the world. Following the acquisition, we own and operate an offshore drilling rig fleet of 62 rigs, with drilling operations in most of the strategic markets around the globe. We also have three rigs under construction. Our rig fleet consists of 12 drillships, 11 dynamically positioned semisubmersible rigs, four moored semisubmersible rigs and 38 jackup rigs. Our offshore rig fleet is one of the world's largest amongst competitive rigs, including one of the newest ultra-deepwater fleets in the industry and a leading premium jackup fleet.

One of our older, less capable rigs is marketed for sale as part of our fleet high-grading strategy and classified as held-for-sale.

Our Industry

Oil prices have rebounded significantly off the 12-year lows experienced during 2016 and have generally stabilized and ranged from around $45 to around $55 per barrel since late last year. We expect market conditions to remain challenging as current contracts expire and new contracts are executed at lower rates. While commodity prices have improved, they have not yet improved to a level that supports increased rig demand sufficient to absorb existing supply and improve pricing power. We believe the current market dynamics will not change until we see a further sustained recovery in commodity prices and/or reduction in rig supply.

While industry conditions remain challenging, customer inquiries have increased in recent months, particularly with respect to shallow-water projects. Despite the increase in customer activity, recent contract awards have generally been for short-term work, subject to an extremely competitive bidding process. The significant oversupply of rigs continues to put downward pressure on day rates, resulting in certain cases whereby rates approximate, or are slightly lower than, direct operating expenses.

Atwood Merger

On May 29, 2017, we entered into an Agreement and Plan of Merger (the “Merger Agreement”) with Atwood and Echo Merger Sub, LLC, our wholly-owned subsidiary, and on October 6, 2017 (the "Merger Date"), we completed our acquisition of Atwood pursuant to the Merger Agreement (the “Merger”).

The Merger is expected to strengthen our position as the leader in offshore drilling across a wide range of water depths around the world. The Merger significantly enhances the capabilities of our rig fleet and improves our ability to meet future customer demand with the highest-specification assets.



As a result of the Merger, Atwood shareholders received 1.60 Ensco Class A Ordinary shares for each share of Atwood common stock, representing a value of $9.33 per share of Atwood common stock 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. Total consideration delivered in the Merger consisted of 134.1 million Class A ordinary shares with an aggregate value of $782.0 million. The estimated fair values assigned to assets acquired net of liabilities assumed exceeded the consideration transferred, resulting in an estimated bargain purchase gain of $167.8 million that will be recognized during the fourth quarter.

Liquidity Position

We have historically relied on our cash flow from continuing operations to meet liquidity needs and fund the majority of our cash requirements. We periodically rely on the issuance of debt and/or equity securities to supplement our liquidity needs. Based on our balance sheet, our contractual backlog and $2.0 billion available under our amended revolving credit facility ("Credit Facility"), we expect to fund our short-term and long-term liquidity needs, including contractual obligations and anticipated capital expenditures, as well as working capital requirements, from cash and cash equivalents, short-term investments, operating cash flows, and, if necessary, funds borrowed under our revolving credit facility or other future financing arrangements. We remain focused on our liquidity and, throughout the market downturn, have executed several transactions to significantly improve our financial position.

Cash and Debt

As of September 30, 2017, we had $4.7 billion in total debt outstanding, representing approximately 36.8% of our total capitalization. We also had $1.8 billion in cash and short-term investments and $2.25 billion undrawn capacity under our Credit Facility.

Upon closing of the Merger, we utilized acquired cash of $445.4 million and cash on hand from the liquidation of short-term investments to repay Atwood's debt and accrued interest of $1.3 billion, resulting in adjusted cash and short-term investments of $926.5 million on a pro forma basis as of September 30, 2017. After adjusting total capital to reflect the $782.0 million equity consideration transferred in the Merger and the estimated $167.8 million bargain purchase gain, our total debt outstanding represented approximately 34.2% of our adjusted total capitalization on a pro forma basis as of September 30, 2017.

Upon closing of the Merger, we amended our Credit Facility to extend the final maturity date by two years. Previously, our Credit Facility had a borrowing capacity of $2.25 billion through September 2019 that declined to $1.13 billion through September 2020. Subsequent to the amendment, our borrowing capacity is $2.0 billion through September 2019 and declines to $1.2 billion through September 2022. The Credit Facility, as amended, requires us to maintain a total debt to total capitalization ratio that is less than or equal to 60%.

In January 2017, through a private-exchange transaction, we repurchased $649.5 million of our outstanding debt with $332.5 million of cash and $332.0 million of newly issued 8.00% senior notes due 2024.

During the nine-month period ended September 30, 2017, we repurchased $194.1 million aggregate principal amount of our outstanding debt for $204.5 million of cash on the open market and recognized an insignificant pre-tax gain, net of discounts, premiums and debt issuance costs.

Our next debt maturity is $237.6 million during 2019, followed by $450.9 million and $269.7 million during 2020 and 2021, respectively.



Backlog

As of September 30, 2017, our backlog was $3.0 billion as compared to $3.6 billion as of December 31, 2016. Our backlog declined primarily due to revenues realized during the first nine months of the year, partially offset by new contract awards and contract extensions. Adjusted for the Merger on a pro forma basis, our backlog as of September 30, 2017 was $3.2 billion. As current contracts expire, we will likely experience declines in backlog, which will result in a decline in revenues and operating cash flows over the near-term. Contract backlog includes the impact of drilling contracts signed or terminated after each respective balance sheet date but prior to filing our annual and quarterly report on February 28, 2017 and October 26, 2017, respectively.
BUSINESS ENVIRONMENT
Floaters

The floater contracting environment continues to be challenged by reduced demand, as well as excess newbuild supply. Floater demand has declined significantly in recent years due to lower commodity prices which have caused our customers to rationalize capital expenditures, resulting in the cancellation and delay of drilling programs. We expect this trend to continue until we see a further sustained recovery in commodity prices.
During the second quarter, we executed contracts for ENSCO DS-4 and ENSCO DS-10 for two-year and one-year terms, respectively. The contracts contain a one-year priced option for ENSCO DS-4 and five one-year priced options for ENSCO DS-10. ENSCO DS-4 began drilling operations offshore Nigeria in August 2017. As a result of the DS-10 contract award, we accelerated delivery to September 2017 and made the final milestone payment of $75.0 million, which was previously deferred into 2019. We expect ENSCO DS-10 to commence drilling operations offshore Nigeria during the first quarter of 2018.

During the third quarter, we executed a six-well contract for ENSCO DS-7, which is expected to commence in March 2018 in the Mediterranean Sea. The contract contains two two-well priced options. Additionally, we executed a one-well extension for ENSCO DS-12 (formerly Atwood Achiever) in direct continuation of its current contract.
Currently, there are approximately 45 competitive newbuild drillships and semisubmersible rigs reported to be under construction, of which approximately 25 are scheduled to be delivered by the end of 2018. 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.
Drilling contractors have retired more than 90 floaters since the beginning of the downturn. Approximately 30 floaters older than 30 years of age are currently idle, and approximately 25 floaters greater than 30 years old have contracts that will expire by the end of 2018 without follow-on work. 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 the majority of these rigs.
Jackups

Demand for jackups has improved with increased tendering activity observed in recent months following historic lows; however, contract terms generally have been short-term in nature and rates remain depressed due to the oversupply of rigs.
During the first quarter, we executed a four-year contract for ENSCO 92 as well as several short-term contracts and contract extensions for ENSCO 68, ENSCO 75, ENSCO 87, ENSCO 106 and ENSCO 107.
During the second quarter, we executed three-year contracts for ENSCO 110 and ENSCO 120 and a 400-day contract for ENSCO 102. We also executed short-term contracts and contract extensions for ENSCO 72, ENSCO 107, ENSCO 121 and ENSCO 122. In addition, we sold ENSCO 56, ENSCO 86, ENSCO 90 and ENSCO 99, which were previously classified as held-for-sale and recognized an insignificant pre-tax gain.


Also during the second quarter, we received notices of termination for convenience for the ENSCO 104 and ENSCO 71 contracts effective in May and August 2017, respectively, which were previously expected to end in January and July 2018, respectively.
During the third quarter, we executed a one-year contract extension for ENSCO 67 and short-term contracts and contract extensions for ENSCO 68, ENSCO 72, ENSCO 101 and ENSCO 115 (formerly Atwood Orca). Additionally, we sold ENSCO 52, which was previously classified as held-for-sale, and recognized an insignificant pre-tax gain. In October, we executed a short-term contract for ENSCO 75.
Currently, there are approximately 95 competitive newbuild jackup rigs reported to be under construction, of which approximately 70 are scheduled to be delivered by the end of 2018. 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 additional rigs may be delayed or cancelled given limited contracting opportunities.

Drilling contractors have retired more than 30 jackups since the beginning of the downturn. Approximately 100 jackups older than 30 years of age are idle. Furthermore, approximately 60 jackups that are 30 years of age or older have contracts that expire before the end of 2018, and these rigs may be unable to find additional work. 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.
RESULTS OF OPERATIONS
The following table summarizes our condensed consolidated results of operations for the three-month and nine-month periods ended September 30, 2017 and 2016 (in millions):
 Three Months Ended
September 30,		 Nine Months Ended
September 30,
 2017 2016 2017 2016
Revenues$460.2
 $548.2
 $1,388.8
 $2,271.8
Operating expenses 
  
  
  
Contract drilling (exclusive of depreciation)285.8
 298.1
 855.2
 1,012.0
Depreciation108.2
 109.4
 325.3
 335.1
General and administrative30.4
 25.3
 86.9
 76.1
Operating income35.8
 115.4
 121.4
 848.6
Other (expense) income, net(40.4) (30.9) (151.3) 114.4
Provision for income taxes23.4
 (3.5) 66.8
 104.6
(Loss) income from continuing operations(28.0) 88.0
 (96.7) 858.4
Loss from discontinued operations, net (.2) (.7) (.4) (1.8)
Net (loss) income(28.2) 87.3
 (97.1) 856.6
Net loss (income) attributable to noncontrolling interests2.8
 (2.0) .5
 (5.4)
Net (loss) income attributable to Ensco$(25.4) $85.3
 $(96.6) $851.2
Revenues declined $88.0 million, or 16%, for the three-month period ended September 30, 2017 as compared to the prior year quarter primarily due to lower average day rates, fewer days under contract across the fleet, lower revenues from various jackup rigs undergoing shipyard projects during the quarter and the sale of ENSCO 52.

Excluding the impact of ENSCO DS-9 and ENSCO 8503 lump-sum termination payments received during the second quarter of 2016 totaling $205.0 million, revenues declined $678.0 million, or 33%, for the nine-month period ended September 30, 2017 as compared to the prior year period. This decline was due primarily to fewer days under contract across the fleet, lower average day rates and the contract terminations and ultimate sale of ENSCO 6003 and ENSCO 6004.


Contract drilling expense declined $12.3 million, or 4%, for the three-month period ended September 30, 2017 as compared to the prior year quarter primarily due to the sale of various jackup rigs and other cost control initiatives that reduced personnel costs.

Contract drilling expense declined $156.8 million, or 15%, for the nine-month period ended September 30, 2017 as compared to the prior year period primarily due to rig stackings, the contract terminations and ultimate sale of ENSCO 6003 and ENSCO 6004, cost control initiatives that reduced personnel costs and the sale of various jackup rigs. This decline was partially offset by contract preparation costs for certain rigs.

Depreciation expense for the three-month period ended September 30, 2017 was consistent with the prior year period. Depreciation expense declined $9.8 million, or 3%, for the nine-month period ended September 30, 2017, primarily due to the extension of useful lives for certain contracted rigs.

General and administrative expenses increased by $5.1 million, or 20%, and $10.8 million, or 14%, for the three-month and nine-month periods ended September 30, 2017, respectively. The increase as compared to the prior year periods was primarily due to transaction costs related to the Merger.

Other (expense) income, net, for the nine-month period ended September 30, 2017 included a pre-tax loss of $6.2 million related to the January 2017 debt exchange. Other (expense) income, net, for the three-month and nine-month periods ended September 30, 2016 included pre-tax gains on debt extinguishment of $18.2 million and $279.0 million, respectively.
A significant number of our drilling contracts are of a long-term nature. Accordingly, an increase or decline in demand for contract drilling services generally affects our operating results and cash flows gradually over future quarters as long-term contracts expire. We expect operating results to decline during 2017 and into 2018 as long-term contracts expire, and our rigs either go uncontracted or we renew contracts at significantly lower rates.

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 September 30, 2017 and 2016:
 2017 2016
Floaters(1)
20 19
Jackups(2) (3)
32 35
Under construction(1)(3)
1 3
Held-for-sale(2) (4)
1 4
Total54 61

(1)
During the third quarter of 2017, we accepted delivery of ENSCO DS-10.
(2)
During the first quarter of 2017, we classified ENSCO 56, ENSCO 86 and ENSCO 99 as held-for-sale. During the second quarter of 2017, we classified ENSCO 52 as held-for-sale.
(3)
During the fourth quarter of 2016, we accepted delivery of ENSCO 141.
(4)
During the fourth quarter of 2016, we sold ENSCO 53 and ENSCO 94. During the second quarter of 2017, we sold ENSCO 56, ENSCO 86, ENSCO 90 and ENSCO 99. During the third quarter of 2017, we sold ENSCO 52.



The following table summarizes our rig utilization and average day rates by reportable segment for the three-month and nine-month periods ended September 30, 2017 and 2016:
 Three Months Ended
September 30,		 Nine Months Ended
September 30,
 2017 2016 2017 2016
Rig Utilization(1)
 
  
  
  
Floaters46% 48% 45% 57%
Jackups60% 55% 63% 61%
Total55% 53% 56% 60%
Average Day Rates(2)
 
  
    
Floaters$334,218
 $353,187
 $336,445
 $360,073
Jackups88,272
 109,379
 87,711
 113,378
Total$165,623
 $183,537
 $159,158
 $196,640
(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 earned but is deferred and amortized over a future period, for example when a rig earns revenue while mobilizing to commence a new contract or while being upgraded in the 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)
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, shipyard contracts and standby contracts.

Operating Income
Our business consists of three operating segments: (1) Floaters, which includes our drillships and semisubmersible rigs, (2) Jackups and (3) Other, which currently consists of management services on rigs owned by third-parties. Our two reportable segments, Floaters and Jackups, provide one service, contract drilling.
Segment information is presented below (in millions).  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 and were included in "Reconciling Items."



Three Months Ended September 30, 2017
 Floaters Jackups Other Operating Segments Total Reconciling Items Consolidated Total
Revenues$291.9
 $153.1
 $15.2
 $460.2
 $—
 $460.2
Operating expenses           
Contract drilling (exclusive of depreciation)139.1
 132.9
 13.8
 285.8
 —
 285.8
Depreciation72.7
 31.6
 —
 104.3
 3.9
 108.2
General and administrative—
 —
 —
 —
 30.4
 30.4
Operating income (loss)$80.1
 $(11.4) $1.4
 $70.1
 $(34.3) $35.8

Three Months Ended September 30, 2016
 Floaters Jackups Other Operating Segments Total Reconciling Items Consolidated Total
Revenues$319.3
 $213.8
 $15.1
 $548.2
 $—
 $548.2
Operating expenses           
Contract drilling (exclusive of depreciation)153.7
 133.2
 11.2
 298.1
 —
 298.1
Depreciation72.9
 32.1
 —
 105.0
 4.4
 109.4
General and administrative—
 —
 —
 —
 25.3
 25.3
Operating income$92.7
 $48.5
 $3.9
 $145.1
 $(29.7) $115.4

Nine Months Ended September 30, 2017
 Floaters Jackups Other Operating Segments Total Reconciling Items Consolidated Total
Revenues$840.7
 $503.8
 $44.3
 $1,388.8
 $—
 $1,388.8
Operating expenses           
Contract drilling (exclusive of depreciation)431.1
 383.8
 40.3
 855.2
 —
 855.2
Depreciation217.5
 95.3
 —
 312.8
 12.5
 325.3
General and administrative—
 —
 —
 —
 86.9
 86.9
Operating income$192.1
 $24.7
 $4.0
 $220.8
 $(99.4) $121.4

Nine Months Ended September 30, 2016
 Floaters Jackups Other Operating Segments Total Reconciling Items Consolidated Total
Revenues$1,468.3
 $743.0
 $60.5
 $2,271.8
 $—
 $2,271.8
Operating expenses           
Contract drilling (exclusive of depreciation)573.6
 390.0
 48.4
 1,012.0
 —
 1,012.0
Depreciation231.0
 90.8
 —
 321.8
 13.3
 335.1
General and administrative—
 —
 —
 —
 76.1
 76.1
Operating income$663.7
 $262.2
 $12.1
 $938.0
 $(89.4) $848.6



Floaters

Floater revenue declined $27.4 million, or 9%, for the three-month period ended September 30, 2017 as compared to the prior year quarter primarily due to fewer days under contract across the fleet and the ENSCO DS-7 contract termination.

Excluding the impact of ENSCO DS-9 and ENSCO 8503 lump-sum termination payments received during the second quarter of 2016 totaling $205.0 million, revenues declined $422.6 million, or 33%, for the nine-month period ended September 30, 2017, respectively, as compared to the prior year period. The decline is primarily due to fewer days under contract across the fleet, the contract terminations and ultimate sale of ENSCO 6003 and ENSCO 6004, lower average day rates and the ENSCO DS-7 contract termination. The declines were partially offset by a higher average day rate for ENSCO DS-6 while operating in Egypt.

Floater contract drilling expense for the three-month period ended September 30, 2017 declined $14.6 million, or 9%, as compared to the prior year period primarily due to rig stackings.

Floater contract drilling expense for the nine-month period ended September 30, 2017 declined $142.5 million, or 25%, as compared to the prior year period primarily due to rig stackings, the contract terminations and ultimate sale of ENSCO 6003 and ENSCO 6004 and other cost control initiatives to reduce personnel costs. These declines were partially offset by contract preparation costs for certain rigs.

Floater depreciation expense for the three-month period ended September 30, 2017 was consistent with the prior year period. Floater depreciation expense for the nine-month period ended September 30, 2017 declined $13.5 million, or 6%, as compared to the prior year period due to the extension of useful lives for certain contracted assets.

Jackups

Jackup revenues declined $60.7 million, or 28%, and $239.2 million, or 32%, for the three-month and nine-month periods ended September 30, 2017, respectively. The decline as compared to the prior year periods was primarily due to lower average day rates, fewer days under contract and various jackup rigs undergoing shipyard projects during the current year periods.

Jackup contract drilling expense for the three-month period ended September 30, 2017 was consistent with the prior year quarter primarily due to the sale of various jackup rigs offset by higher operating costs for rigs that were stacked in the prior year period.

Jackup contract drilling expense for the nine-month period ended September 30, 2017 declined $6.2 million, or 2%, as compared to the prior year period primarily due to the sale of various rigs and cost control initiatives to reduce personnel costs, partially offset by higher repair costs and rig reactivation costs during the period.

Jackup depreciation expense for the three-month period ended September 30, 2017 was consistent with the prior year period. Jackup depreciation expense for the nine-month period ended September 30, 2017 declined $4.5 million, or 5%, as compared to the prior year primarily due to the extension of useful lives for certain contracted assets.


Other Income (Expense)
The following table summarizes other income (expense) for the three-month and nine-month periods ended September 30, 2017 and 2016 (in millions):
 Three Months Ended
September 30,		 Nine Months Ended
September 30,
 2017 2016 2017 2016
Interest income$7.5
 $3.8
 $22.3
 $8.6
Interest expense, net:

  
    
Interest expense(72.6) (65.1) (221.9) (209.0)
Capitalized interest24.5
 11.7
 54.9
 36.5
 (48.1) (53.4) (167.0) (172.5)
Other, net.2
 18.7
 (6.6) 278.3
 $(40.4) $(30.9) $(151.3) $114.4
Interest income for the three-month and nine-month periods ended September 30, 2017 increased as compared to the prior year periods as a result of higher short-term investment balances.

Interest expense for the three-month and nine-month periods ended September 30, 2017 increased as compared to the prior year periods due to the issuance of $849.5 million in convertible notes and $332.0 million in exchange notes during 2016 and 2017, respectively, partially offset by the repurchase of $2.0 billion of debt during 2016 and 2017. Interest expense capitalized during the three-month and nine-month periods ended September 30, 2017 increased as compared to the prior year periods due to an increase in the amount of capital invested in newbuild construction.

Other expense, net, for the nine-month period ended September 30, 2017 included a pre-tax loss of $6.2 million related to the January 2017 debt exchange. Other income, net, for the three-month and nine-month periods ended September 30, 2016 included pre-tax gains on debt extinguishment of $18.2 million and $279.0 million, respectively, related to debt repurchases.

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 of $800,000 and $4.9 million, inclusive of offsetting fair value derivatives, were included in other, net, for the three-month and nine-month periods ended September 30, 2017, respectively. Net foreign currency exchange losses of $600,000 and $2.4 million, inclusive of offsetting fair value derivatives, were included in other, net, for the three-month and nine-month periods ended September 30, 2016, respectively.

Gains from the change in fair value of our supplemental executive retirement plans (the "SERP") of $1.0 million and $3.5 million were included in other, net, for the three-month and nine-month periods ended September 30, 2017, respectively. Gains from the change in fair value of our SERP of $1.1 million and $1.6 million were included in other, net, for the three-month and nine-month periods ended September 30, 2016, respectively.

Provision for Income Taxes
Ensco 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 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 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.

Income tax expense for the three-month and nine-month periods ended September 30, 2017 was $23.4 million and $66.8 million, respectively, as compared to an income tax benefit of $3.5 million and income tax expense of $104.6 million during the respective prior year periods. The changes in income tax expense from the prior year periods results from changes in overall profitability and changes in the mix of our profits and losses generated in tax jurisdictions with different tax rates.
LIQUIDITY AND CAPITAL RESOURCES

We have historically relied on our cash flow from continuing operations to meet liquidity needs and fund the majority of our cash requirements. We periodically rely on the issuance of debt and/or equity securities to supplement our liquidity needs. A substantial portion of our operating cash flow has been invested in the expansion and enhancement of our drilling rig fleet through newbuild construction and upgrade projects and the return of capital to shareholders through dividend payments. We expect that cash flow generated during 2017 will primarily be used to fund capital expenditures, repurchase debt and repay Atwood's debt.

Upon closing of the Merger, we amended our Credit Facility to extend the final maturity date by two years. Previously, our Credit Facility had a borrowing capacity of $2.25 billion through September 2019 that declined to $1.13 billion through September 2020. Subsequent to the amendment, our borrowing capacity is $2.0 billion through September 2019 and declines to $1.2 billion through September 2022. Further, we utilized acquired cash of $445.4 million and cash on hand from the liquidation of short-term investments to repay Atwood's debt and accrued interest of $1.3 billion.

In January 2017, through a private-exchange transaction, we repurchased $649.5 million of our outstanding debt with $332.5 million of cash and $332.0 million of newly issued 8.00% senior notes due 2024.    

During the nine-month period ended September 30, 2017, we repurchased $194.1 million aggregate principal amount of our outstanding debt for $204.5 million of cash on the open market and recognized an insignificant pre-tax gain, net of discounts, premiums and debt issuance costs.

Our Board of Directors declared a $0.01 per share quarterly cash dividend during the first, second and third quarters. The declaration and amount of future dividends is at the discretion of our Board of Directors. In the future, our Board of Directors may, without advance notice, reduce or suspend our dividend in order to maintain our financial flexibility and best position us for long-term success. When evaluating dividend payment timing and amounts, our Board of Directors considers several factors, including our profitability, liquidity, financial condition, market outlook, reinvestment opportunities, capital requirements and limitations under our Credit Facility.

During the nine-month period ended September 30, 2017, our primary sources of cash were net maturities of short-term investments of $372.7 million and $219.6 million generated from operating activities of continuing operations. Our primary uses of cash for the same period were $537.0 million for the repurchase of debt and $474.1 million for the construction, enhancement and other improvement of our drilling rigs.



During the nine-month period ended September 30, 2016, our primary sources of cash were $1.0 billion generated from operating activities of continuing operations and $585.5 million in proceeds from our equity offering. Our primary uses of cash for the same period were $862.4 million for the repurchase of debt,$255.5 million for the construction, enhancement and other improvement of our drilling rigs and net purchases of short-term investments of $122.0 million.

Cash Flow and Capital Expenditures
Our cash flow from operating activities of continuing operations and capital expenditures for the nine-month periods ended September 30, 2017 and 2016 were as follows (in millions):
 2017 2016
Cash flow from operating activities of continuing operations$219.6
 $994.8
Capital expenditures 
  
New rig construction$397.8
 $155.7
Rig enhancements25.6
 15.6
Minor upgrades and improvements50.7
 84.2
 $474.1
 $255.5
Excluding the impact of ENSCO DS-9 and ENSCO 8503 lump-sum termination payments of $205.0 million received during the nine-months ended September 30, 2016, cash flow from operating activities of continuing operations declined$570.2 million, or 72%, for the nine-month period ended September 30, 2017 as compared to the prior year period. The decline primarily resulted from a $785.2 million decline in net cash receipts from contract drilling services, offset by a $169.7 million decline in net cash payments for contract drilling services, a $13.8 million decline in cash payments for taxes and a $9.1 million decline in cash payments for interest, net of interest income.

During the third quarter, we accepted delivery and made the final milestone payment of $75.0 million for ENSCO DS-10, which was previously deferred into 2019. We currently have one premium jackup rig under construction scheduled for delivery during the first quarter of 2018. Following the Merger, we have two ultra-deepwater drillships under construction, ENSCO DS-13 (formerly Atwood Admiral) and ENSCO DS-14 (formerly Atwood Archer), which are scheduled for delivery in June 2019 and September 2020, respectively, or such earlier date that we elect to take delivery with 45 days' notice.
The following table summarizes the cumulative amount of contractual payments made as of September 30, 2017 for our rigs under construction and estimated timing of our remaining contractual payments, inclusive of rigs acquired in the Merger (in millions):
  
Cumulative Paid(1)
 Remaining 2017 
2018
and
2019
 
2020
and
2021
 Thereafter 
Total(2)
ENSCO 123 $63.3
 $2.2
 $215.3
 $—
 $—
 $280.8
ENSCO DS-13(3)
 —
 —
 —
 —
 83.9
 83.9
ENSCO DS-14(3)
 —
 —
 15.0
 —
 165.0
 180.0
  $63.3
 $2.2
 $230.3
 $—
 $248.9
 $544.7

(1)
Cumulative paid represents the aggregate amount of contractual payments made from commencement of the construction agreement through September 30, 2017. Contractual payments made by Atwood prior to the Merger for ENSCO DS-13 (formerly Atwood Admiral) and ENSCO DS-14 (formerly Atwood Archer) are excluded.

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



(3)
The remaining milestone payments bear interest at a rate of 4.5% per annum, which accrues during the holding period until delivery. 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 5% per annum with a maturity date of December 31, 2022 and will be secured by a mortgage on each respective rig.
The actual timing of these expenditures may vary based on the completion of various construction milestones, which are, to a large extent, beyond our control.    

Based on our current projections, we expect capital expenditures during 2017 to include approximately $456 million for newbuild construction, approximately $57 million for rig enhancement projects and approximately $73 million for minor upgrades and improvements. Depending on market conditions and future opportunities, we may make additional capital expenditures to upgrade rigs for customer requirements and construct or acquire additional rigs.

Financing and Capital Resources
Exchange Offers

In January 2017, we completed exchange offers (the "Exchange Offers") to exchange our outstanding 8.50% senior notes due 2019, 6.875% senior notes due 2020 and 4.70% senior notes due 2021 for 8.00% senior notes due 2024 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 8.00% Senior notes due 2024 Consideration 
Cash Consideration(1)
 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
Total $649.5
 $332.0
 $332.5
 $664.5

(1)
As of December 31, 2016, the aggregate amount of principal repurchased with cash of $332.5 million, along with associated premiums, was classified as current maturities of long-term debt on our condensed consolidated balance sheet.

During the first quarter, we recognized a net pre-tax loss on the Exchange Offers of $6.2 million, consisting of a loss of $3.5 million that includes the write-off of premiums on tendered debt and $2.7 million of transaction costs.



Open Market Repurchases

During the nine-month period ended September 30, 2017, we repurchased certain of our outstanding senior notes with cash on hand and recognized an insignificant pre-tax gain, net of discounts, premiums and debt issuance costs. The aggregate repurchases were as follows (in millions):
 Aggregate Principal Amount Repurchased 
Aggregate Repurchase Price(1)
8.50% Senior notes due 2019$54.6
 $60.1
6.875% Senior notes due 2020100.1
 105.1
4.70% Senior notes due 202139.4
 39.3
Total$194.1
 $204.5

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

Maturities

Our next debt maturity is $237.6 million during 2019, followed by $450.9 million and $269.7 million during 2020 and 2021, respectively.

Debt to Capital

Our total debt, total capital and total debt to total capital ratios are summarized below (in millions, except percentages):
 
Pro Forma(1)
September 30, 2017
 September 30,
2017		 December 31,
2016
Total debt$4,747.7
 $4,747.7
 $5,274.5
Total capital (2)
$13,862.7
 $12,912.9
 $13,525.1
Total debt to total capital34.2% 36.8% 39.0%

(1)
Pro forma amounts reflect the impact of the Merger as if it occurred on September 30, 2017. Total capital was adjusted to reflect the $782.0 million equity consideration transferred and the estimated $167.8 million bargain purchase gain. Upon closing of the Merger, we utilized acquired cash of $445.4 million and cash on hand from the liquidation of short-term investments to repay Atwood's debt and accrued interest of $1.3 billion.

(2)
Total capital consists of total debt and Ensco shareholders' equity.

Revolving Credit Facility

In October 2017, we amended our Credit Facility to extend the final maturity date by two years. Previously, our Credit Facility had a borrowing capacity of $2.25 billion through September 2019 that declined to $1.13 billion through September 2020. Subsequent to the amendment, our borrowing capacity is $2.0 billion through September 2019 and declines to $1.2 billion through September 2022. The credit agreement governing our revolving credit facility includes an accordion feature allowing us to increase the commitments expiring in September 2022 up to an aggregate amount not to exceed $1.5 billion.

Also in October, Moody's downgraded our credit rating from B1 to B2 and Standard & Poor's downgraded our credit rating from BB to B+. The Credit Facility amendment and the rating actions resulted in increases to the interest rates applicable to borrowings. The applicable margin rates are 2.50% per annum for Base Rate advances and


3.50% per annum for LIBOR advances. In addition, our quarterly commitment fee increased as a result of the amendment and rating actions to 0.625% per annum on the undrawn portion of the $2.0 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 $750 million 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 continue paying 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 $150 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 September 30, 2017, we were in compliance in all material respects with our covenants under the Credit Facility. We had no amounts outstanding under the Credit Facility as of September 30, 2017 and December 31, 2016.

Our access to credit and capital markets depends on the credit ratings assigned to our debt. 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 available options when accessing credit and capital markets, or when restructuring or refinancing debt. In addition, future financings or refinancings may result in higher borrowing costs and require more restrictive terms and covenants, which may further restrict our operations. With a credit rating below investment grade, we have no access to the commercial paper market.

Other Financing

We filed an automatically effective shelf registration statement on Form S-3 with the U.S. Securities and Exchange Commission on January 15, 2015, 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, as amended, expires in January 2018.

During 2013, our shareholders approved a new share repurchase program. Subject to certain provisions under English law, including the requirement of Ensco plc to have sufficient distributable reserves, we may repurchase shares up to a maximum of $2.0 billion in the aggregate under the program, but in no case more than 35.0 million shares. As of September 30, 2017, no shares have been repurchased under the program. The program terminates in May 2018.

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 that are able to be redeemed, pursuant to their terms. In connection with any exchange, we may issue equity, issue new debt 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. There can be no assurance that an active trading market will exist for our outstanding senior notes following any such transactions.


Other Commitments

As of September 30, 2017, we were contingently liable for an aggregate amount of $83.5 million under outstanding letters of credit and surety bonds which 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 and surety bonds are not normally called, as we typically comply with the underlying performance requirement. As of September 30, 2017, we were not required to make any collateral deposits with respect to these agreements.

Liquidity
Our liquidity position is summarized in the table below (in millions, except ratios):
 
Pro Forma
September 30, 2017
 September 30,
2017		 December 31,
2016
Cash and cash equivalents$724.4
 $724.4
 $1,159.7
Short-term investments$202.1
 $1,069.8
 $1,442.6
Working capital$1,228.3
 $1,972.8
 $2,424.9
Current ratio3.3
 5.0
 3.8

The pro forma amounts reflect the impact of the Merger as if it occurred on September 30, 2017. Upon closing of the Merger, we utilized acquired cash of $445.4 million and cash on hand from the liquidation of short-term investments to repay Atwood's debt and accrued interest of $1.3 billion. Pro forma working capital and current ratio reflects the aforementioned, in addition to other current assets acquired and current liabilities assumed of $175.3 million and $59.3 million, respectively.

We expect to fund our short-term liquidity needs, including contractual obligations and anticipated capital expenditures, as well as working capital requirements, from our cash and cash equivalents, short-term investments, operating cash flows and, if necessary, funds borrowed under our revolving credit facility.

We expect to fund our long-term liquidity needs, including contractual obligations and anticipated capital expenditures, from our operating cash flows and, if necessary, funds borrowed under our revolving credit facility or other future financing arrangements.

We may decide to access debt and/or equity markets to raise additional capital or increase liquidity as necessary. 
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 September 30, 2017, we had cash flow hedges outstanding to exchange an aggregate $164.0 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 fair value of the underlying hedged items. As of September 30, 2017, we held derivatives not designated as hedging instruments to exchange an aggregate $137.1 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 September 30, 2017 would approximate $15.1 million. Approximately $13.7 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 derivative counterparties 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. 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 of our derivatives mature during the next 18 months. See Note 4 to our condensed consolidated financial statements for additional information on our derivative instruments.
CRITICAL ACCOUNTING POLICIES

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 condensed consolidated financial statements and accompanying notes. Our significant accounting policies are included in Note 1 to our audited consolidated financial statements for the year ended December 31, 2016 included in our annual report on Form 10-K filed with the SEC on February 28, 2017. These policies, along with our underlying judgments and assumptions made in their application, have a significant impact on our condensed 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 by management regarding estimates in matters that are inherently uncertain. Our critical accounting policies are those related to property and equipment, impairment of long-lived assets and income taxes. For a discussion of the critical accounting policies and estimates that we use in the preparation of our condensed consolidated financial statements, see "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Critical Accounting Policies and Estimates" in Part II of our annual report on Form 10-K for the year ended December 31, 2016, in addition to supplemental disclosure regarding impairment of long-lived assets set forth in Item 2 of our quarterly report on Form 10-Q for the quarter ended June 30, 2017.


New Accounting Pronouncements
See Note 1 to our condensed consolidated financial statements included in "Item 1. Financial Statements" for information on new accounting pronouncements.

Item 3.   Quantitative and Qualitative Disclosures About Market Risk
Information required under Item 3. has been incorporated into "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations - Market Risk."

Item 4.   Controls and Procedures
Based on their evaluation as of the end of the period covered by this quarterly report on Form 10-Q, our Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures, as defined in Rule 13a-15 under the Securities Exchange Act of 1934, are effective.
During the fiscal quarter ended September 30, 2017, 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.




PART II - OTHER INFORMATION


Item 1.   Legal Proceedings
Brazil Internal Investigation

Pride International LLC, formerly Pride International, Inc. (“Pride”), a company we acquired in 2011, commenced drilling operations in Brazil in 2001. In 2008, Pride entered into a drilling services agreement with Petrobras (the "DSA") for ENSCO DS-5, a drillship ordered from Samsung Heavy Industries, a shipyard in South Korea ("SHI"). Beginning in 2006, Pride conducted periodic compliance reviews of its business with Petrobras, and, after the acquisition of Pride, Ensco conducted similar compliance reviews.

We commenced a compliance review in early 2015 after media reports were released regarding ongoing investigations of various kickback and bribery schemes in Brazil involving Petrobras. While conducting our compliance review, we became aware of an internal audit report by Petrobras alleging irregularities in relation to the DSA. Upon learning of the Petrobras internal audit report, our Audit Committee appointed independent counsel to lead an investigation into the alleged irregularities. Further, in June and July 2015, we voluntarily contacted the SEC and the DOJ, respectively, to advise them of this matter and of our Audit Committee’s investigation. Independent counsel, under the direction of our Audit Committee, has substantially completed its investigation by reviewing and analyzing available documents and correspondence and interviewing current and former employees involved in the DSA negotiations and the negotiation of the ENSCO DS-5 construction contract with SHI (the "DS-5 Construction Contract").

To date, our Audit Committee has found no credible evidence that Pride or Ensco or any of their current or former employees were aware of or involved in any wrongdoing, and our Audit Committee has found no credible evidence linking Ensco or Pride to any illegal acts committed by our former marketing consultant who provided services to Pride and Ensco in connection with the DSA. Independent counsel has continued to provide the SEC and DOJ with updates throughout the investigation, including detailed briefings regarding its investigation and findings. We entered into a one-year tolling agreement with the DOJ that expired in December 2016. We extended our tolling agreement with the SEC for 12 months until March 2018.

Subsequent to initiating our Audit Committee investigation, Brazilian court documents connected to the prosecution of former Petrobras directors and employees as well as certain other third parties, including our former marketing consultant, referenced the alleged irregularities cited in the Petrobras internal audit report. Our former marketing consultant has entered into a plea agreement with the Brazilian authorities. On January 10, 2016, Brazilian authorities filed an indictment against a former Petrobras director. This indictment states that the former Petrobras director received bribes paid out of proceeds from a brokerage agreement entered into for purposes of intermediating a drillship construction contract between SHI and Pride, which we believe to be the DS-5 Construction Contract. The parties to the brokerage agreement were a company affiliated with a person acting on behalf of the former Petrobras director, a company affiliated with our former marketing consultant, and SHI. The indictment alleges that amounts paid by SHI under the brokerage agreement ultimately were used to pay bribes to the former Petrobras director. The indictment does not state that Pride or Ensco or any of their current or former employees were involved in the bribery scheme or had any knowledge of the bribery scheme.

On January 4, 2016, we received a notice from Petrobras declaring the DSA void effective immediately. Petrobras’ notice alleges that our former marketing consultant both received and procured improper payments from SHI for employees of Petrobras and that Pride had knowledge of this activity and assisted in the procurement of and/or facilitated these improper payments. We disagree with Petrobras’ allegations. See "DSA Dispute" below for additional information.



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 SHI and Pride in relation to the DSA.  The Brazilian authorities requested information regarding our compliance program and the findings of our internal investigations. We are cooperating with the Office of the Attorney General and have provided documents in response to their request.  We cannot predict the scope or ultimate outcome of this procedure or whether any other 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. If the SEC or DOJ determines that violations of the FCPA have occurred, or if any governmental authority determines that we have violated applicable anti-bribery laws, they could seek civil and criminal sanctions, including monetary penalties, against us, as well as changes to our business practices and compliance programs, any of which could have a material adverse effect on our business and financial condition. Our customers, business partners and other stakeholders could seek to take actions adverse to our interests. Further, investigating and resolving such allegations is expensive and could consume significant management time and attention. Although our internal investigation is substantially complete, we cannot predict whether any additional allegations will be made or whether any additional facts relevant to the investigation will be uncovered during the course of the investigation and what impact those allegations and additional facts will have on the timing or conclusions of the investigation. Our Audit Committee will examine any such additional allegations and additional facts and the circumstances surrounding them.

DSA Dispute

As described above, on January 4, 2016, Petrobras sent a notice to us declaring the DSA void effective immediately, reserving its rights and stating its intention to seek any restitution to which it may be entitled. We disagree with Petrobras’ declaration that the DSA is void. We believe that Petrobras repudiated the DSA and have therefore accepted the DSA as terminated on April 8, 2016 (the "Termination Date"). At this time, we cannot reasonably determine the validity of Petrobras' claim or the range of our potential exposure, if any. As a result, there can be no assurance as to how this dispute will ultimately be resolved.

We did not recognize revenue for amounts owed to us under the DSA from the beginning of the fourth quarter of 2015 through the Termination Date as we concluded that collectability of these amounts was not reasonably assured. Additionally, our receivables from Petrobras related to the DSA from prior to the fourth quarter of 2015 are fully reserved in our condensed consolidated balance sheet as of September 30, 2017. We have initiated arbitration proceedings in the U.K. against Petrobras seeking payment of all amounts owed to us under the DSA, in addition to any other amounts to which we are entitled, and intend to vigorously pursue our claims. Petrobras subsequently filed a counterclaim seeking restitution of certain sums paid under the DSA less value received by Petrobras under the DSA. We have also initiated separate arbitration proceedings in the U.K. against SHI for any losses we have incurred in connection with the foregoing. SHI subsequently filed a statement of defense disputing our claim. There can be no assurance as to how these arbitration proceedings will ultimately be resolved.

Pride FCPA Investigation

During 2010, Pride and its subsidiaries resolved their previously disclosed investigations into potential violations of the U.S. Foreign Corrupt Practices Act of 1977 (the "FCPA") with the DOJ and SEC. The settlement with the DOJ included a deferred prosecution agreement (the "DPA") between Pride and the DOJ and a guilty plea by Pride Forasol S.A.S., one of Pride’s subsidiaries, to FCPA-related charges. During 2012, the DOJ moved to (i) dismiss the charges against Pride and end the DPA one year prior to its scheduled expiration; and (ii) terminate the unsupervised probation of Pride Forasol S.A.S. The Court granted the motions.

Pride has received preliminary inquiries from governmental authorities of certain countries referenced in its settlements with the DOJ and SEC. We could face additional fines, sanctions and other penalties from authorities in these and other relevant jurisdictions, including prohibition of our participating in or curtailment of business operations in certain jurisdictions and the seizure of rigs or other assets. At this stage of such inquiries, we are unable to determine what, if any, legal liability may result. Our customers in certain jurisdictions could seek to impose penalties or take other actions adverse to our business. We could also face other third-party claims by directors, officers, employees,


affiliates, advisors, attorneys, agents, stockholders, debt holders or other stakeholders. In addition, disclosure of the subject matter of the investigations and settlements could adversely affect our reputation and our ability to obtain new business or retain existing business, to attract and retain employees and to access the capital markets.

We cannot currently predict what, if any, actions may be taken by any other applicable government or other authorities or our customers or other third parties or the effect any such actions may have on our financial position, operating results or cash flows.

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 2016, 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 or cash flows, there can be no assurance as to the ultimate outcome of these assessments. A $200,000 liability related to these matters was included in accrued liabilities and other on our condensed consolidated balance sheet as of September 30, 2017.
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 million, for an alleged environmental spill originating from ENSCO 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. We do not know at this time what, if any, involvement we may have in this investigation.
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 or cash flows, there can be no assurance as to the ultimate outcome of the proceedings.

Atwood Merger

On June 23, 2017, a putative class action captioned Bernard Stern v. Atwood Oceanics, Inc., et al, was filed in the U.S. District Court for the Southern District of Texas against Atwood, Atwood’s directors, Ensco and Merger Sub. The Stern complaint generally alleges that Atwood and the Atwood directors disseminated a false or misleading registration statement on Form S-4 (the “Registration Statement”) on June 16, 2017, which omitted material information regarding the proposed Merger, in violation of Section 14(a) of the Exchange Act. Specifically, the Stern complaint alleges that Atwood and the Atwood directors omitted material information regarding the parties’ financial projections, the analysis performed by Atwood’s financial advisor, Goldman Sachs & Co. LLC (“Goldman Sachs”), in support of its fairness opinion, the timing and nature of communications regarding post-transaction employment of Atwood's directors and officers, potential conflicts of interest of Goldman Sachs, and whether there were further discussions with another potential acquirer of Atwood following the May 30, 2017 announcement of the Merger. The Stern complaint further alleges that the Atwood directors, Ensco and Merger Sub are liable for these violations as “control persons” of Atwood under Section 20(a) of the Exchange Act. With respect to Ensco, the Stern complaint alleges that Ensco had direct supervisory control over the composition of the Registration Statement. The Stern complaint seeks injunctive relief, including to enjoin the Merger, rescissory damages, and an award of attorneys’ fees in addition to other relief.



On June 27, 2017, June 29, 2017 and June 30, 2017, additional putative class actions captioned Joseph Composto v. Atwood Oceanics, Inc., et al, Booth Family Trust v. Atwood Oceanics, Inc., et al and Mary Carter v. Atwood Oceanics, Inc., et al, respectively, were filed in the U.S. District Court for the Southern District of Texas against Atwood and Atwood’s directors. These actions allege violations of Sections 14(a) and 20(a) of the Exchange Act by Atwood and Atwood’s directors similar to those alleged in the Stern complaint; however, neither Ensco plc nor Merger Sub is named as a defendant in these actions. On October 2, 2017, the actions were consolidated and the Stern matter was designated as the lead case. The plaintiffs subsequently voluntarily dismissed the actions.

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 or cash flows.
Item 1A.Risk Factors

There are numerous factors that affect our business and results of operations, many of which are beyond our control. In addition to information set forth in this quarterly report, you should 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 our annual report on Form 10-K for the year ended December 31, 2016, as well as “Item 1A. Risk Factors” in Part II of our quarterly report on Form 10-Q for the quarter ended June 30, 2017, each of2020, which contains descriptions of significant risks that mightmay cause our actual results of operations in future periods to differ materially from those currently anticipated or expected. There have been no material changes from the risks previously disclosed in our annual report on Form 10-K for the year ended December 31, 2016, except as set forth below and in our quarterly report on Form 10-Q for the quarter ended June 30, 2017.


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

We consummated the Merger with the expectation that it would result in various benefits, including, among others, the expansion of our asset base and creation of synergies. We closed the Merger on October 6, 2016, however, achieving the anticipated benefits of the Merger is subject to a number of uncertainties, including whether the Atwood 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 Merger. Our combined operations could be adversely affected by issues attributable to Atwood’s historical operations that arose or are based on events or actions that occurred prior to the completion of the Merger. In addition, integrating Atwood’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 as well as economic trends, could adversely affect our ability to realize the expected benefits from the Merger.




Item 2.   Unregistered Sales of Equity Securities and Use of Proceeds
 
The following table below provides a summary of our repurchases of our equity securities during the quarter ended September 30, 2017:March 31, 2021:
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
January 1 - January 311,289 $0.05 — $500,000,000 
February 1 - February 2844,467 $0.09 — $500,000,000 
March 1 - March 31356 $0.09 — $500,000,000 
Total 46,112 $0.09 —  

(1)During the three months ended March 31, 2021, 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 for Valaris plc to have sufficient distributable reserves and for the Board to conclude that a repurchase is in the best interests of Valaris plc taking into account the interests of relevant stakeholders, 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 March 31, 2021, there had been no share repurchases under the repurchase program. Our DIP Facility only permits the repurchase of shares of our common stock in certain circumstances and the repurchase of shares would likely require approval of the bankruptcy court. We do not currently expect to make repurchases under the program while Valaris plc remains subject to chapter 11 bankruptcy proceedings.

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Issuer Purchases of Equity Securities
 
 
 
 
 
 
 
Period
Total Number of Securities Purchased(1)
 Average Price Paid per Security 
Total Number of Securities Purchased as Part of Publicly Announced Plans or Programs (2)   
 Approximate Dollar Value of Securities that May Yet Be Purchased Under Plans or Programs
        
July 1 - July 311,701
 $4.69
 —
 $2,000,000
August 1 - August 312,491
 $5.25
 —
 $2,000,000
September 1 - September 303,136
 $4.53
 —
 $2,000,000
Total 7,328
 $4.81
 —
  


Item 3. Defaults Upon Senior Securities

See "Part I, Item 1. Notes to Condensed Consolidated Financial Statements" – "Note 2, Chapter 11 Proceedings and Ability to Continue as a Going Concern" and "Note 10, Debt", which are incorporated in this item by reference.

Item 6.   Exhibits
(1)
During the quarter ended September 30, 2017, 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)
During 2013, our shareholders approved a new share repurchase program. Subject to certain provisions under English law, including the requirement of Ensco plc to have sufficient distributable reserves, we may repurchase up to a maximum of $2.0 billion in the aggregate under the program, but in no case more than 35.0 million shares. As of September 30, 2017, no shares have been repurchased under the program.The program terminates in May 2018.



Item 6.   Exhibits

Exhibit NumberExhibit
2.1
Agreement andFourth Amended Joint Chapter 11 Plan of Merger, dated asReorganization of May 29, 2017,Valaris plc and its Debtor Affiliates Pursuant to Chapter 11 of the Bankruptcy Code (incorporated by and among Ensco plc, Echo Merger Sub LLC and Atwood Oceanics, Inc. (incorporated by referencereference to Exhibit 2.1A of Order Confirming the Debtor's Fourth Amended Joint Chapter 11 Plan of Reorganization, filed as Exhibit 99.1 to the Registrant's CurrentCurrent Report on Form 8-K filed on May 30, 2017, March 5, 2021, File No. 1-08097)No . 001-08097).
10.1*15.1
Commitment Agreement and Fifth Amendment to Fourth Amended and Restated Credit Agreement, dated as of October 3, 2017, among Ensco, Pride International LLC, certain other subsidiaries of Ensco party thereto, Citibank, N.A., as administrative agent, and the lenders party thereto (incorporated by reference to Exhibit 10.1 to the Registrant's Current Report on Form 8-K filed on October 6, 2017, File No. 1-08097).
*12.1
Computation of ratio of earnings to fixed charges.
*15.1
Letter regarding unaudited interim financial information.
*31.1
Certification of the Chief Executive Officer of Registrant Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*31.2
Certification of the Chief Financial Officer of Registrant Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
**32.1
Certification of the Chief Executive Officer of Registrant Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
**32.2
Certification of the Chief Financial Officer of Registrant Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*101.INSXBRL Instance Document - The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
*101.SCHInline XBRL Taxonomy Extension Schema Document
*101.CALInline XBRL Taxonomy Extension Calculation Linkbase Document
*101.DEFInline XBRL Taxonomy Extension Definition Linkbase Document
*101.LABInline XBRL Taxonomy Extension Label Linkbase Document
*101.PREInline XBRL Taxonomy Extension Presentation Linkbase Document
*104The cover page of our Quarterly Report on Form 10-Q for the quarter ended March 31, 2021, formatted in Inline XBRL (included with Exhibit 101 attachments).
*   Filed herewith.
** Furnished herewith.



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SIGNATURES
 
Pursuant to the requirements 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.
 
 
Valaris plc
Date:April 28, 2021/s/ JONATHAN H. BAKSHT
Jonathan H. Baksht
Executive Vice President and
Chief Financial Officer
(principal financial officer)
Ensco plc/s/ COLLEEN W. GRABLE
Date: October 26, 2017/s/ JONATHAN H. BAKSHT
Jonathan H. Baksht
Senior Vice President and
Chief Financial Officer
(principal financial officer)
/s/ TOMMY E. DARBY  
Tommy E. Darby
Colleen W. Grable
Controller

(principal accounting officer)



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