UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
(Mark One)
| | | | | |
| ☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended June 30, 2021March 31, 2022
OR
| | | | | |
| ☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from __________ to__________
Commission File Number 1-8097
Valaris Limited
(Exact name of registrant as specified in its charter)
| | | | | | | | | | | | | | |
| Bermuda | | 98-1589854 |
(State or other jurisdiction of
incorporation or organization) | | (I.R.S. Employer
Identification No.) |
| | | | |
| Clarendon House, 2 Church Street | | |
| Hamilton | Bermuda | | HM 11 |
| (Address of principal executive offices) | | (Zip Code) |
Registrant's telephone number, including area code: +44 (0) 20 7659 4660
Securities registered pursuant to Section 12(b) of the Act:
| | | | | | | | | | | | | | |
| Title of each class | | Ticker Symbol(s) | | Name of each exchange on which registered |
| Common Shares, $0.01 par value share | | VAL | | New York Stock Exchange |
| Warrants to purchase Common Shares | | VAL WS | | New York Stock Exchange |
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See 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 | | ☒☐ |
| | | | | | |
| Non-Accelerated filer | | ☐ | | Smaller reporting company | | ☒☐ |
| | | | | | |
| | | | Emerging growth company | | ☐ |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒
Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Section 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court.
Yes ☒ No ☐
As of July 29, 2021,April 28, 2022, there were 75,000,045 Common Shares75,001,107 common shares of the registrant issued and outstanding.
VALARIS LIMITED
INDEX TO FORM 10-Q
FOR THE QUARTER ENDED JUNE 30, 2021MARCH 31, 2022
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; the impact of our emergence from bankruptcy; expected utilization, day rates, revenues, operating expenses, cash flows, contract status, terms and duration, contract backlog, capital expenditures, insurance, financing and funding; the effect, impact, potential duration and other implications of the ongoing COVID-19 pandemic; impact of our emergence from bankruptcy; the offshore drilling market, including supply and demand, customer drilling programs, stacking of rigs, effects of new rigs on the market and effectseffect of declines inthe volatility of commodity prices; expected work commitments, awards, contracts and contracts;letters of intent; 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),reactivations, 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; general political conditions, including political tensions, conflicts and war (such as the ongoing conflict in Ukraine); future operations; the impact of increasing regulatory complexity; the outcome of tax disputes, assessments and settlements; synergies and 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, particularlyincluding:
•delays in lightcontract commencement dates or cancellation, suspension, renegotiation or termination (with or without cause, including those due to impacts of difficultthe COVID-19 pandemic) of drilling contracts or drilling programs as a result of general or industry-specific economic conditions, mechanical difficulties, performance, delays in the delivery of critical drilling equipment, failure of the customer to receive final investment decision (FID) for which the drilling rig was contracted or other reasons;
•changes in worldwide rig supply and demand, competition or technology, including as a result of delivery of newbuild drilling rigs or reactivation of stacked drilling rigs;
•requirements to make significant expenditures in connection with rig reactivations, customer drilling requirements and to comply with governing laws or regulations in the regions we operate;
•loss of a significant customer or customer contract, as well as customer consolidation and changes to customer strategy, including focusing on renewable energy projects;
•our ability to attract and retain skilled personnel on commercially reasonable terms, whether due to labor regulations, rising wages, unionization, or otherwise, or to retain employees;
•governmental policies that could reduce demand for hydrocarbons, including mandating or incentivizing the conversion from internal combustion engine powered vehicles to electric-powered vehicles;
•consumer preferences for alternative fuels and electric-powered vehicles, as part of the global energy transition, may lead to reduced demand for our services;
•increased scrutiny from regulators, market conditions, including:and industry participants, stakeholders and others in regards to our Environmental, Social and Governance ("ESG") practices and reporting responsibilities;
•the impactoccurrence of cybersecurity incidents, attacks or other breaches to our emergence from bankruptcy oninformation technology systems, including our businessrig operating systems;
•potential additional asset impairments;
•the adequacy of sources of liquidity for us and relationships and comparability of our financial results, as well as the dilutive impacts of warrants issues pursuant to the plan of reorganization;customers;
•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 shutdown 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 business, as a result of 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 (“OPEC+”), which could result in increased volatility in prices for oil and natural gas that could affect the markets for our services;
•decreases in levels ofrisks inherent to drilling activity and capital expenditures by our customers, whether as a result of the global capital markets and liquidity, prices of oil and natural gasrig reactivations, repair, modification or otherwise, which may cause us to idle or stack additional rigs;
•upgrades, unexpected delays in contractequipment delivery, engineering, design or commissioning issues following delivery, or changes in the commencement, datescompletion or cancellation, suspension, renegotiation or termination (with or without cause, including those 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;
•the occurrence of cybersecurity incidents, attacks or other breaches to our information technology systems, including our rig operating systems;
•increased scrutiny from regulators, market and industry participants, stakeholders and others regarding our Environmental, Social and Governance (ESG) practices and reporting responsibilities;
•the costs, disruption and diversion of our management's attention associated with campaigns by activist securityholders;
•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 our bankruptcy and our emergence from chapter 11;
•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;
•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, or as a result of our financial condition generally;dates;
•internal control risk due to significant employee reductions;reductions and changes in management;
•changes in worldwide rig supplyour ability to generate operational efficiencies from our shared services center and demand, competition or technology, including as a resultpotential risks relating to the processing of deliverytransactions and recording of newbuild drilling 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;financial information;
•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;
•our customers cancelling or shortening the duration of our drilling contracts, cancelling future drilling programs and seeking pricing and other contract concessions from us;
•decreases in 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, climate change concerns or otherwise, which may cause us to idle, stack or retire additional rigs;
•governmental action, terrorism, cyber-attacks, piracy, military action and political and economic uncertainties, including 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, Southeast Asia, Eastern Europe or other geographic areas, which may result in expropriation, nationalization, confiscation or deprivation or destruction of our assets; or suspension and/or termination of contracts based on force majeure events or adverse environmental safety events; or volatility in prices of oil and natural gas;
•risks inherent to shipyard rig construction, repair, modification or upgrades, unexpected delaysdisputes over production levels among members of the Organization of Petroleum Exporting Countries and other oil and gas producing nations (“OPEC+”), which could result in equipment delivery, engineering, design or commissioning issues following delivery, or changesincreased volatility in prices for oil and natural gas that could affect the commencement, completion or service dates;markets for our services;
•our ability to enter into, and the terms of, future drilling contracts, including contracts for our newbuild 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;
•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;
•environmental or other liabilities, risks, damages or losses, whether related to storms, hurricanes or other weather-related events (including wreckage or debris removal), collisions, groundings, blowouts, fires, explosions, other accidents,cyberattacks, terrorism cyber-attacks or otherwise, for which insurance coverage and contractual indemnities may be insufficient, unenforceable or otherwise unavailable;
•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;
•the impact of our emergence from bankruptcy on our business and relationships and comparability of our financial results, as well as the potentially dilutive impacts of warrants issued pursuant to the plan of reorganization;
•the costs, disruption and diversion of our management's attention associated with campaigns by activist securityholders;
•economic volatility and political, legal and tax uncertainties following the U.K.'s exit from the European Union; and
•adverse changes in foreign currency exchange rates, including their effect on the fair value measurement of any derivative instruments that we may enter into.
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, 2020,2021, 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.
PART I - FINANCIAL INFORMATION
Item 1.Financial Statements
VALARIS LIMITED AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In millions, except per share amounts)
(Unaudited)
| | | Successor | | | Predecessor | | Successor | | | | Predecessor |
| | Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2020 | | Three Months Ended March 31, 2022 | | | | Three Months Ended March 31, 2021 |
| | OPERATING REVENUES | OPERATING REVENUES | $ | 202.8 | | | | $ | 90.3 | | | $ | 388.8 | | OPERATING REVENUES | $ | 318.4 | | | | | $ | 307.1 | |
| OPERATING EXPENSES | OPERATING EXPENSES | | | | | OPERATING EXPENSES | | | | |
| Contract drilling (exclusive of depreciation) | Contract drilling (exclusive of depreciation) | 168.7 | | | | 85.6 | | | 370.7 | | Contract drilling (exclusive of depreciation) | 331.3 | | | | | 253.6 | |
| Loss on impairment | Loss on impairment | 0 | | | | 0 | | | 838.0 | | Loss on impairment | — | | | | | 756.5 | |
| Depreciation | Depreciation | 16.6 | | | | 37.5 | | | 131.5 | | Depreciation | 22.5 | | | | | 122.1 | |
| General and administrative | General and administrative | 12.7 | | | | 6.4 | | | 62.6 | | General and administrative | 18.8 | | | | | 24.3 | |
| Total operating expenses | Total operating expenses | 198.0 | | | | 129.5 | | | 1,402.8 | | Total operating expenses | 372.6 | | | | | 1,156.5 | |
| | EQUITY IN EARNINGS (LOSSES) OF ARO | 4.8 | | | | 1.2 | | | (5.2) | | |
| OPERATING INCOME (LOSS) | 9.6 | | | | (38.0) | | | (1,019.2) | | |
| EQUITY IN EARNINGS OF ARO | | EQUITY IN EARNINGS OF ARO | 4.3 | | | | | 1.9 | |
| OPERATING LOSS | | OPERATING LOSS | (49.9) | | | | | (847.5) | |
| OTHER INCOME (EXPENSE) | OTHER INCOME (EXPENSE) | | | | OTHER INCOME (EXPENSE) | | | | | |
| Interest income | Interest income | 7.8 | | | | 1.0 | | | 5.7 | | Interest income | 10.9 | | | | | 2.6 | |
| Interest expense, net (Unrecognized contractual interest expense for debt subject to compromise was $32.6 million for the one month ended April 30, 2021) | (8.0) | | | | (1.1) | | | (116.2) | | |
| Interest expense, net (Unrecognized contractual interest expense for debt subject to compromise was $100.3 million for the three months ended March 31, 2021) | | Interest expense, net (Unrecognized contractual interest expense for debt subject to compromise was $100.3 million for the three months ended March 31, 2021) | (11.5) | | | | | (1.3) | |
| Reorganization items, net | Reorganization items, net | (4.1) | | | | (3,532.4) | | | 0 | | Reorganization items, net | (1.0) | | | | | (52.2) | |
| Other, net | Other, net | 5.7 | | | | (1.2) | | | 5.1 | | Other, net | 11.0 | | | | | 22.5 | |
| | | 1.4 | | | | (3,533.7) | | | (105.4) | | | 9.4 | | | | | (28.4) | |
| INCOME (LOSS) BEFORE INCOME TAXES | 11.0 | | | | (3,571.7) | | | (1,124.6) | | |
| LOSS BEFORE INCOME TAXES | | LOSS BEFORE INCOME TAXES | (40.5) | | | | | (875.9) | |
| PROVISION (BENEFIT) FOR INCOME TAXES | PROVISION (BENEFIT) FOR INCOME TAXES | | | | PROVISION (BENEFIT) FOR INCOME TAXES | | | | |
| Current income tax expense | 14.0 | | | | 3.6 | | | 13.8 | | |
| Current income tax expense (benefit) | | Current income tax expense (benefit) | (0.1) | | | | | 30.8 | |
| Deferred income tax expense (benefit) | Deferred income tax expense (benefit) | 1.1 | | | | (19.1) | | | (29.6) | | Deferred income tax expense (benefit) | (0.6) | | | | | 0.9 | |
| | | 15.1 | | | | (15.5) | | | (15.8) | | | (0.7) | | | | | 31.7 | |
| NET LOSS | NET LOSS | (4.1) | | | | (3,556.2) | | | (1,108.8) | | NET LOSS | (39.8) | | | | | (907.6) | |
| NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS | NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS | (2.1) | | | | (.8) | | | 1.4 | | NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS | 1.2 | | | | | (2.4) | |
| NET LOSS ATTRIBUTABLE TO VALARIS | NET LOSS ATTRIBUTABLE TO VALARIS | $ | (6.2) | | | | $ | (3,557.0) | | | $ | (1,107.4) | | NET LOSS ATTRIBUTABLE TO VALARIS | $ | (38.6) | | | | | $ | (910.0) | |
| LOSS PER SHARE - BASIC AND DILUTED | LOSS PER SHARE - BASIC AND DILUTED | $ | (0.08) | | | | $ | (17.81) | | | $ | (5.58) | | LOSS PER SHARE - BASIC AND DILUTED | $ | (0.51) | | | | | $ | (4.56) | |
| WEIGHTED-AVERAGE SHARES OUTSTANDING | WEIGHTED-AVERAGE SHARES OUTSTANDING | | | | WEIGHTED-AVERAGE SHARES OUTSTANDING | | | | |
| Basic and Diluted | Basic and Diluted | 75.0 | | | | 199.7 | | | 198.6 | | Basic and Diluted | 75.0 | | | | | 199.6 | |
The accompanying notes are an integral part of these condensed consolidated financial statements.
VALARIS LIMITED AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONSCOMPREHENSIVE LOSS
(In millions, except per share amounts)millions)
(Unaudited)
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor |
| Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 |
| | | | | | |
| OPERATING REVENUES | $ | 202.8 | | | | $ | 397.4 | | | $ | 845.4 | |
| OPERATING EXPENSES | | | | | | |
| Contract drilling (exclusive of depreciation) | 168.7 | | | | 337.8 | | | 846.7 | |
| Loss on impairment | 0 | | | | 756.5 | | | 3,646.2 | |
| Depreciation | 16.6 | | | | 159.6 | | | 296.0 | |
| General and administrative | 12.7 | | | | 30.7 | | | 116.0 | |
| Total operating expenses | 198.0 | | | | 1,284.6 | | | 4,904.9 | |
| | | | | | |
| EQUITY IN EARNINGS (LOSSES) OF ARO | 4.8 | | | | 3.1 | | | (11.5) | |
| OPERATING INCOME (LOSS) | 9.6 | | | | (884.1) | | | (4,071.0) | |
| OTHER INCOME (EXPENSE) | | | | | | |
| Interest income | 7.8 | | | | 3.6 | | | 10.5 | |
| Interest expense, net (Unrecognized contractual interest expense for debt subject to compromise was $132.9 million for the four months ended April 30, 2021) | (8.0) | | | | (2.4) | | | (229.4) | |
| Reorganization items, net | (4.1) | | | | (3,584.6) | | | 0 | |
| Other, net | 5.7 | | | | 19.9 | | | 5.6 | |
| | 1.4 | | | | (3,563.5) | | | (213.3) | |
| INCOME (LOSS) BEFORE INCOME TAXES | 11.0 | | | | (4,447.6) | | | (4,284.3) | |
| PROVISION (BENEFIT) FOR INCOME TAXES | | | | | | |
| Current income tax expense (benefit) | 14.0 | | | | 34.4 | | | (58.7) | |
| Deferred income tax expense (benefit) | 1.1 | | | | (18.2) | | | (109.1) | |
| | 15.1 | | | | 16.2 | | | (167.8) | |
| NET LOSS | (4.1) | | | | (4,463.8) | | | (4,116.5) | |
| NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS | (2.1) | | | | (3.2) | | | 2.8 | |
| NET LOSS ATTRIBUTABLE TO VALARIS | $ | (6.2) | | | | $ | (4,467.0) | | | $ | (4,113.7) | |
| LOSS PER SHARE - BASIC AND DILUTED | $ | (0.08) | | | | $ | (22.38) | | | $ | (20.75) | |
| WEIGHTED-AVERAGE SHARES OUTSTANDING | | | | | | |
| Basic and Diluted | 75.0 | | | | 199.6 | | | 198.3 | |
| | | | | | | | | | | | | | | | |
| Successor | | | | | Predecessor |
| Three Months Ended March 31, 2022 | | | | | Three Months Ended March 31, 2021 |
| | | | | | |
| NET LOSS | $ | (39.8) | | | | | | $ | (907.6) | |
| OTHER COMPREHENSIVE LOSS, NET | | | | | | |
| | | | | | |
| Net reclassification adjustment for amounts recognized in net loss as a component of net periodic benefit | — | | | | | | 0.1 | |
| Reclassification of net gains on derivative instruments from other comprehensive loss into net loss | — | | | | | | (5.6) | |
| Other | (0.3) | | | | | | 0.2 | |
| NET OTHER COMPREHENSIVE LOSS | (0.3) | | | | | | (5.3) | |
| COMPREHENSIVE LOSS | (40.1) | | | | | | (912.9) | |
| COMPREHENSIVE (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS | 1.2 | | | | | | (2.4) | |
| COMPREHENSIVE LOSS ATTRIBUTABLE TO VALARIS | $ | (38.9) | | | | | | $ | (915.3) | |
The accompanying notes are an integral part of these condensed consolidated financial statements.
VALARIS LIMITED AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSSBALANCE SHEETS
(In millions)millions, except par value amounts)
(Unaudited)
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor |
| Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2020 |
| | | | | | |
| NET LOSS | $ | (4.1) | | | | $ | (3,556.2) | | | $ | (1,108.8) | |
| OTHER COMPREHENSIVE LOSS, NET | | | | | | |
| Net change in fair value of derivatives | 0 | | | | 0 | | | 4.8 | |
| | | | | | |
| Reclassification of net gains on derivative instruments from other comprehensive loss into net loss | 0 | | | | 0 | | | (10.9) | |
| Other | (.2) | | | | (.2) | | | 0 | |
| NET OTHER COMPREHENSIVE LOSS | (.2) | | | | (.2) | | | (6.1) | |
| COMPREHENSIVE LOSS | (4.3) | | | | (3,556.4) | | | (1,114.9) | |
| COMPREHENSIVE (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS | (2.1) | | | | (0.8) | | | 1.4 | |
| COMPREHENSIVE LOSS ATTRIBUTABLE TO VALARIS | $ | (6.4) | | | | $ | (3,557.2) | | | $ | (1,113.5) | |
| | | | | | | | | | | | | |
| | | |
| March 31,
2022 | | December 31,
2021 | | |
| (Unaudited) | | | | |
| ASSETS | | | | | |
| CURRENT ASSETS | | | | | |
| Cash and cash equivalents | $ | 578.2 | | | $ | 608.7 | | | |
| Restricted cash | 30.0 | | | 35.9 | | | |
| Accounts receivable, net | 439.3 | | | 444.2 | | | |
| Other current assets | 125.7 | | | 117.8 | | | |
| Total current assets | 1,173.2 | | | 1,206.6 | | | |
| PROPERTY AND EQUIPMENT, AT COST | 1,018.8 | | | 957.0 | | | |
| Less accumulated depreciation | 88.6 | | | 66.1 | | | |
| Property and equipment, net | 930.2 | | | 890.9 | | | |
| LONG-TERM NOTES RECEIVABLE FROM ARO | 256.8 | | | 249.1 | | | |
| INVESTMENT IN ARO | 90.9 | | | 86.6 | | | |
| OTHER ASSETS | 186.6 | | | 176.0 | | | |
| | $ | 2,637.7 | | | $ | 2,609.2 | | | |
| LIABILITIES AND SHAREHOLDERS' EQUITY | | | | | |
| CURRENT LIABILITIES | | | | | |
| Accounts payable - trade | $ | 311.2 | | | $ | 225.8 | | | |
| Accrued liabilities and other | 212.1 | | | 196.2 | | | |
| | | | | |
| | | | | |
| Total current liabilities | 523.3 | | | 422.0 | | | |
| LONG-TERM DEBT | 545.5 | | | 545.3 | | | |
| OTHER LIABILITIES | 544.8 | | | 581.1 | | | |
| Total liabilities | 1,613.6 | | | 1,548.4 | | | |
| | | | | |
| COMMITMENTS AND CONTINGENCIES | 0 | | 0 | | |
| VALARIS SHAREHOLDERS' EQUITY | | | | | |
| | | | | |
| | | | | |
| Common shares, $0.01 par value, 700 shares authorized, 75 shares issued as of March 31, 2022 and December 31, 2021 | 0.8 | | | 0.8 | | | |
| Preference shares, $0.01 par value, 150 shares authorized, 0 shares issued as of March 31, 2022 and December 31, 2021 | — | | | — | | | |
| Stock warrants | 16.4 | | | 16.4 | | | |
| Additional paid-in capital | 1,086.4 | | | 1,083.0 | | | |
| | | | | |
| Retained deficit | (71.6) | | | (33.0) | | | |
| Accumulated other comprehensive loss | (9.4) | | | (9.1) | | | |
| | | | | |
| Total Valaris shareholders' equity | 1,022.6 | | | 1,058.1 | | | |
| NONCONTROLLING INTERESTS | 1.5 | | | 2.7 | | | |
| Total equity | 1,024.1 | | | 1,060.8 | | | |
| | $ | 2,637.7 | | | $ | 2,609.2 | | | |
The accompanying notes are an integral part of these condensed consolidated financial statements.
VALARIS LIMITED AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS
(In millions)
(Unaudited)
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor |
| Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 |
| | | | | | |
| NET LOSS | $ | (4.1) | | | | $ | (4,463.8) | | | $ | (4,116.5) | |
| OTHER COMPREHENSIVE LOSS, NET | | | | | | |
| Net changes in pension and postretirement plan assets and benefit obligations recognized in other comprehensive income (loss) | 0 | | | | .1 | | | 0 | |
| Net change in derivative fair value | 0 | | | | 0 | | | (8.1) | |
| Reclassification of net gains on derivative instruments from other comprehensive loss into net loss | 0 | | | | (5.6) | | | (11.0) | |
| Other | (.2) | | | | 0 | | | (.4) | |
| NET OTHER COMPREHENSIVE LOSS | (.2) | | | | (5.5) | | | (19.5) | |
| COMPREHENSIVE LOSS | (4.3) | | | | (4,469.3) | | | (4,136.0) | |
| COMPREHENSIVE (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS | (2.1) | | | | (3.2) | | | 2.8 | |
| COMPREHENSIVE LOSS ATTRIBUTABLE TO VALARIS | $ | (6.4) | | | | $ | (4,472.5) | | | $ | (4,133.2) | |
The accompanying notes are an integral part of these condensed consolidated financial statements.
VALARIS LIMITED AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In millions, except share and par value amounts)
| | | | | | | | | | | | | | | | |
| Successor | | | Predecessor |
| June 30,
2021 | | | December 31,
2020 | | |
| (Unaudited) | | | | | |
| ASSETS | | | | | | |
| CURRENT ASSETS | | | | | | |
| Cash and cash equivalents | $ | 608.8 | | | | $ | 325.8 | | | |
| Restricted cash | 53.1 | | | | 11.4 | | | |
| Accounts receivable, net | 436.1 | | | | 449.2 | | | |
| Other current assets | 119.7 | | | | 386.5 | | | |
| Total current assets | 1,217.7 | | | | 1,172.9 | | | |
| PROPERTY AND EQUIPMENT, AT COST | 914.4 | | | | 13,209.3 | | | |
| Less accumulated depreciation | 16.6 | | | | 2,248.8 | | | |
| Property and equipment, net | 897.8 | | | | 10,960.5 | | | |
| LONG-TERM NOTES RECEIVABLE FROM ARO | 234.3 | | | | 442.7 | | | |
| INVESTMENT IN ARO | 85.4 | | | | 120.9 | | | |
| OTHER ASSETS | 166.5 | | | | 176.2 | | | |
| | $ | 2,601.7 | | | | $ | 12,873.2 | | | |
| LIABILITIES AND SHAREHOLDERS' EQUITY | | | | | | |
| CURRENT LIABILITIES | | | | | | |
| Accounts payable - trade | $ | 183.9 | | | | $ | 176.4 | | | |
| Accrued liabilities and other | 212.7 | | | | 250.4 | | | |
| | | | | | |
| | | | | | |
| Total current liabilities | 396.6 | | | | 426.8 | | | |
| LONG-TERM DEBT | 544.8 | | | | 0 | | | |
| OTHER LIABILITIES | 569.8 | | | | 762.4 | | | |
| Total liabilities not subject to compromise | 1,511.2 | | | | 1,189.2 | | | |
| LIABILITIES SUBJECT TO COMPROMISE | 0 | | | | 7,313.7 | | | |
| COMMITMENTS AND CONTINGENCIES | 0 | | | 0 | | |
| VALARIS SHAREHOLDERS' EQUITY | | | | | | |
| Predecessor Class A ordinary shares, U.S. $0.40 par value, 206.1 million shares issued as of December 31, 2020 | 0 | | | | 82.5 | | | |
| Predecessor Class B ordinary shares, £1 par value, 50,000 shares issued as of December 31, 2020 | 0 | | | | .1 | | | |
| Successor common shares, $0.01 par value, 700 million shares authorized, 75 million shares issued as of June 30, 2021 | .8 | | | | 0 | | | |
| Successor preference shares, $0.01 par value, 150 million shares authorized, 0 shares issued as of June 30, 2021 | 0 | | | | 0 | | | |
| Successor stock warrants | 16.4 | | | | 0 | | | |
| Additional paid-in capital | 1,078.7 | | | | 8,639.9 | | | |
| | | | | | |
| Retained deficit | (6.2) | | | | (4,183.8) | | | |
| Accumulated other comprehensive loss | (.2) | | | | (87.9) | | | |
| Predecessor Treasury shares, at cost, 6.6 million shares as of December 31, 2020 | 0 | | | | (76.2) | | | |
| Total Valaris shareholders' equity | 1,089.5 | | | | 4,374.6 | | | |
| NONCONTROLLING INTERESTS | 1.0 | | | | (4.3) | | | |
| Total equity | 1,090.5 | | | | 4,370.3 | | | |
| | $ | 2,601.7 | | | | $ | 12,873.2 | | | |
The accompanying notes are an integral part of these condensed consolidated financial statements.
VALARIS LIMITED AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions)
(Unaudited)
| | | Successor | | | Predecessor | | Successor | | | | Predecessor |
| | | Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 | | Three Months Ended March 31, 2022 | | | | Three Months Ended March 31, 2021 |
| | OPERATING ACTIVITIES | OPERATING ACTIVITIES | | | | | | OPERATING ACTIVITIES | | | | | |
| Net loss | Net loss | $ | (4.1) | | | | $ | (4,463.8) | | | $ | (4,116.5) | | Net loss | $ | (39.8) | | | | | $ | (907.6) | |
| Adjustments to reconcile net loss to net cash used in operating activities: | | | | |
| | Adjustments to reconcile net loss to net cash provided by (used in) operating activities: | | Adjustments to reconcile net loss to net cash provided by (used in) operating activities: | | | | |
| Depreciation expense | Depreciation expense | 16.6 | | | | 159.6 | | | 296.0 | | Depreciation expense | 22.5 | | | | | 122.1 | |
| Accretion of discount on shareholders note | Accretion of discount on shareholders note | (6.0) | | | | 0 | | | 0 | | Accretion of discount on shareholders note | (7.7) | | | | | — | |
| Equity in losses (earnings) of ARO | (4.8) | | | | (3.1) | | | 11.5 | | |
| Equity in earnings of ARO | | Equity in earnings of ARO | (4.3) | | | | | (1.9) | |
| Net periodic pension and retiree medical income | | Net periodic pension and retiree medical income | (4.0) | | | | | (4.0) | |
| Share-based compensation expense | | Share-based compensation expense | 3.4 | | | | | 3.8 | |
| Gain on asset disposals | | Gain on asset disposals | (2.5) | | | | | (1.4) | |
| Amortization, net | | Amortization, net | 1.6 | | | | | (4.6) | |
| Deferred income tax expense (benefit) | Deferred income tax expense (benefit) | 1.1 | | | | (18.2) | | | (109.1) | | Deferred income tax expense (benefit) | (0.6) | | | | | 0.9 | |
| Debt discounts and other | .4 | | | | 0 | | | 28.8 | | |
| Amortization, net | (.3) | | | | (4.8) | | | 12.2 | | |
| Reorganization items, net | 0 | | | | 3,487.3 | | | 0 | | |
| Amortization of debt issuance cost | | Amortization of debt issuance cost | 0.2 | | | | | — | |
| Loss on impairment | Loss on impairment | 0 | | | | 756.5 | | | 3,646.2 | | Loss on impairment | — | | | | | 756.5 | |
| Share-based compensation expense | 0 | | | | 4.8 | | | 13.5 | | |
| | Adjustment to gain on bargain purchase | 0 | | | | 0 | | | 6.3 | | |
| | | Other | Other | (2.5) | | | | (4.1) | | | (2.7) | | Other | — | | | | | 5.8 | |
| Changes in operating assets and liabilities | Changes in operating assets and liabilities | (25.7) | | | | 68.5 | | | (156.7) | | Changes in operating assets and liabilities | 32.5 | | | | | 20.9 | |
| Contributions to pension plans and other post-retirement benefits | Contributions to pension plans and other post-retirement benefits | (0.6) | | | | (22.5) | | | (10.6) | | Contributions to pension plans and other post-retirement benefits | (0.8) | | | | | (22.2) | |
| Net cash used in operating activities | (25.9) | | | | (39.8) | | | (381.1) | | |
| Net cash provided by (used in) operating activities | | Net cash provided by (used in) operating activities | 0.5 | | | | | (31.7) | |
| INVESTING ACTIVITIES | INVESTING ACTIVITIES | | | | | | INVESTING ACTIVITIES | | | | | |
| Additions to property and equipment | Additions to property and equipment | (8.1) | | | | (8.7) | | | (67.1) | | Additions to property and equipment | (38.5) | | | | | (6.0) | |
| Net proceeds from disposition of assets | Net proceeds from disposition of assets | .2 | | | | 30.1 | | | 13.8 | | Net proceeds from disposition of assets | 1.3 | | | | | 3.7 | |
| | Net cash provided by (used in) investing activities | (7.9) | | | | 21.4 | | | (53.3) | | |
| FINANCING ACTIVITIES | | | | | | |
| | Issuance of First Lien Notes | 0 | | | | 520.0 | | | 0 | | |
| Payments to Predecessor creditors | 0 | | | | (129.9) | | | 0 | | |
| Borrowings on credit facility | 0 | | | | 0 | | | 566.0 | | |
| | Repayments of credit facility borrowings | 0 | | | | 0 | | | (15.0) | | |
| Reduction of long-term borrowings | 0 | | | | 0 | | | (9.7) | | |
| Net cash used in investing activities | | Net cash used in investing activities | (37.2) | | | | | (2.3) | |
| | Other | 0 | | | | (1.4) | | | (1.9) | | |
| Net cash provided by financing activities | 0 | | | | 388.7 | | | 539.4 | | |
| | FINANCING ACTIVITIES | | FINANCING ACTIVITIES | — | | | | | — | |
| | Effect of exchange rate changes on cash and cash equivalents and restricted cash | Effect of exchange rate changes on cash and cash equivalents and restricted cash | (.3) | | | | (.1) | | | (.2) | | Effect of exchange rate changes on cash and cash equivalents and restricted cash | 0.3 | | | | | (0.1) | |
| INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS AND RESTRICTED CASH | (34.1) | | | | 370.2 | | | 104.8 | | |
| DECREASE IN CASH AND CASH EQUIVALENTS AND RESTRICTED CASH | | DECREASE IN CASH AND CASH EQUIVALENTS AND RESTRICTED CASH | (36.4) | | | | | (34.1) | |
| CASH AND CASH EQUIVALENTS AND RESTRICTED CASH, BEGINNING OF PERIOD | CASH AND CASH EQUIVALENTS AND RESTRICTED CASH, BEGINNING OF PERIOD | 696.0 | | | | 325.8 | | | 97.2 | | CASH AND CASH EQUIVALENTS AND RESTRICTED CASH, BEGINNING OF PERIOD | 644.6 | | | | | 325.8 | |
| CASH AND CASH EQUIVALENTS AND RESTRICTED CASH, END OF PERIOD | CASH AND CASH EQUIVALENTS AND RESTRICTED CASH, END OF PERIOD | $ | 661.9 | | | | $ | 696.0 | | | $ | 202.0 | | CASH AND CASH EQUIVALENTS AND RESTRICTED CASH, END OF PERIOD | $ | 608.2 | | | | | $ | 291.7 | |
The accompanying notes are an integral part of these condensed consolidated financial statements.
VALARIS LIMITED AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Note 1 -Unaudited Condensed Consolidated Financial Statements
We prepared the accompanying condensed consolidated financial statements of Valaris Limited and its subsidiaries (the "Company," "Valaris," "Successor," "our," "we"("Valaris" or "us""Successor") 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, 20202021 Condensed Consolidated Balance Sheet data was derived from our 20202021 audited consolidated financial statements but does 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.
Results of operations for the three months ended March 31, 2022 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2022. 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, 2021.
On
Summary of Significant Accounting Policies
Please refer to "Note 1. Description of the Business and Summary of Significant Accounting Policies" of our Consolidated Financial Statements from our Form 10-K for the year ended December 31, 2021, filed with the SEC on February 22, 2022, for the discussion of our significant accounting policies. Certain previously reported amounts have been reclassified to conform to the current year presentation.
Emergence from Chapter 11 Bankruptcy and Fresh Start Accounting
As described in "Note 1. Description of the Business and Summary of Significant Accounting Policies", "Note. 2 Chapter 11 Proceedings" and "Note 3. Fresh Start Accounting" from our 2021 Form 10-K, we filed voluntary petitions for bankruptcy on August 19, 2020 (the "Petition Date"“Petition Date”), Valaris plc ("Legacy Valaris" or "Predecessor") and certain of its direct and indirect subsidiaries (collectively, the "Debtors"), filed voluntary petitions for reorganization under chapter 11 of the 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").
In connection with the Chapter 11 Cases, on and prior to April 30, 2021 (the "Effective Date"), Legacy Valaris effectuated certain restructuring transactions, pursuant to which the successor company, Valaris, was formed and through a series of transactions Legacy Valaris transferred to a subsidiary of the Successor substantially all of the subsidiaries, and other assets, of Legacy Valaris. emerged from bankruptcy.
References to the financial position and results of operations of the "Successor" or "Successor Company" relate to the financial position and results of operations of the CompanyValaris Limited, together with its consolidated subsidiaries, after the Effective Date. References to the financial position and results of operations of the "Predecessor" or "Predecessor Company" refer to the financial position and results of operations of Valaris plc ("Legacy ValarisValaris"), together with its consolidated subsidiaries, on and prior to the Effective Date. References to the “Company,” “we,” “us” or “our” in this Quarterly Report are to Valaris Limited, together with its consolidated subsidiaries, when referring to periods following the Effective Date, and to Legacy Valaris, together with its consolidated subsidiaries, when referring to periods prior to and including the Effective Date.
Results of operations for the four months ended April 30, 2021 (Predecessor) and two months ended June 30, 2021 (Successor) are not necessarily indicative of the results of operations that will be realized from June 30, 2021to December 31, 2021 (Successor), or for any future period. 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, 2020, filed with the SEC on March 2, 2021.
Bankruptcy and Fresh Start Accounting
On the Effective Date, the Debtors emerged from the Chapter 11 Cases. Upon emergence from the Chapter 11 Cases, we qualified for and adoptedapplied fresh start accounting. The application of fresh start accounting resulted in a new basis of accounting, and the Companywe became a new entity for financial reporting purposes. Accordingly, our financial statements and notes after the Effective Date are not comparable to our financial statements and notes on and prior to that date. Furthermore, the unauditedThe condensed consolidated financial statements and notes have been presented with a black line division to delineate the lack of comparability between the Predecessor and Successor.
See“Note 2 – Chapter 11 Proceedings” and "Note 3 - Fresh Start Accounting" for additional details regarding the bankruptcy and fresh start accounting.
Changes in Accounting Policies
Upon emergence from bankruptcy, we elected to change our accounting policies related to property and equipment as well as materials and supplies.
Prior to emergence from bankruptcy, we recorded our drilling rigs as a single asset with a useful life ascribed by the expected useful life of that asset. Upon emergence, we have identified the significant components of our drilling rigs and ascribed useful lives based on the expected time until the next required overhaul or the end of the expected economic lives of the components.
Historically, we recognized materials and supplies on the balance sheet when purchased and subsequently expensed items when consumed. Following emergence, materials and supplies will be expensed as a period cost when received. Additionally, a customer arrangement provides that we take title to their materials and supplies for the duration of the contract and return or pay cash for them at the termination of the contract. Together with our policy change on materials and supplies, we elected to record these assets and the obligation to our customer on a net basis as opposed to on a gross basis.
New Accounting Pronouncements
Recently adopted accounting pronouncements
Income TaxesLeases - In December 2019,July 2021, the FASBFinancial Accounting Standards Board ("FASB") issued ASU 2019-12,Accounting Standards Update ("ASU") No. 2021-05, Income Taxes“Leases (Topic 740): Simplifying the Accounting for Income Taxes842); Lessors - Certain Leases with Variable Lease Payments”, ("“Update 2019-12"2021-05”), which removes certain exceptionsrequires a lessor to classify a lease with entirely or partially variable payments that do not depend on an index or rate as an operating lease if another classification (i.e. sales-type or direct financing) would trigger a day-one loss. Update 2021-05 is effective for investments, intraperiod allocations and interim tax 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.fiscal years beginning after December 15, 2021, with early adoption permitted. We adopted Update 2019-12 effectivethis update January 1, 20212022 using a prospective method, with no material impact to our condensed consolidated financial statements upon adoption.statements.
Accounting pronouncements to be adopted
Reference Rate Reform - In March 2020, the FASB issued ASU No. 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 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. Our notes receivable with ARO, from which we generate interest income on a LIBOR-based rate, are impacted by the application of this standard. As the notes bear interest on the LIBOR rate determined at the end of the preceding year, the rate governing our interest income in 2022 has already been determined. We are inexpect to be able to modify the processterms of evaluatingour notes receivable to a comparable interest rate before the applicable LIBOR rate is no longer available and as such, do not expect this standard to have a material impact this amendment will have onto our condensed consolidated financial statements.
LeasesBusiness Combinations -In JulyOctober 2021, the FASB issued ASU 2021-05, No. 2021-08, “Leases (Topic 842); LessorsAccounting for Contracts Assets and Contract Liabilities from Contracts with Customers” (“Update 2021-08”). ASU No. 2021-08 requires an entity (acquirer) to recognize and measure contract assets and contract liabilities acquired in a business combination in accordance with Topic 606 and provides practical expedients for acquirers when recognizing and measuring acquired contract assets and contract liabilities from revenue contracts in a business combination. The amendments also apply to contract assets and contract liabilities from other contracts to which the provisions of Topic 606 apply, such as contract liabilities for the sale of nonfinancial assets within the scope of Subtopic 610-20, Other Income - Certain LeasesGains and Losses from the Derecognition of Nonfinancial Assets. The FASB issued the update to improve the accounting for acquired revenue contracts with Variable Lease Payments, ("customers in a business combination. Update 2021-05") which requires a lessor to classify a lease with entirely or partially variable payments that do not depend on an index or rate as an operating lease if another classification (i.e. sales-type or direct financing) would trigger a day-one loss. Update 2021-052021-08 is effective for fiscal years beginning after December 15, 2021,2022, and interim periods within those fiscal years, with early adoption permitted. We arewill adopt Update 2021-08 in the process of evaluatingperiod required and will apply it to any business combination completed subsequent to the impact this amendment will have on our condensed consolidated financial statements.adoption.
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
Chapter 11 Cases and Emergence from Chapter 11
On the Petition Date, 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.
On the Effective Date, we successfully completed our financial restructuring and together with the Debtors emerged from the Chapter 11 Cases. Upon emergence from the Chapter 11 Cases, we eliminated $7.1 billion of debt and obtained a $520 million capital injection by issuing the first lien secured notes (the "First Lien Notes"). See “Note 11 - Debt" for additional information on the First Lien Notes. On the Effective Date, the Legacy Valaris Class A ordinary shares were cancelled and common shares of Valaris with a nominal value of $0.01 per share (“Common Shares”) were issued. Also, former holders of Legacy Valaris' equity were issued warrants (the "Warrants") to purchase Common Shares.
Below is a summary of the terms of the plan of reorganization:
•Appointed six new members to the Company's Board of Directors to replace all of the directors of Legacy Valaris, other than the director also serving as President and Chief Executive Officer, who was re-appointed pursuant to the plan of reorganization. All but one of the seven new directors, became directors as of the Effective Date and one became a director on July 1, 2021.
•Obligations under Legacy Valaris's outstanding senior notes (the "Senior Notes") were cancelled and the related indentures were cancelled, except to the limited extent expressly set forth in the plan of reorganization and the holders thereunder received the treatment as set forth in the plan of reorganization;
•The Legacy Valaris revolving credit facility (the "Revolving Credit Facility") was terminated and the holders thereunder received the treatment as set forth in the plan of reorganization;
•Holders of the Senior Notes received their pro rata share of (1) 38.48%, or 28,859,900, of Common Shares and (2) approximately 97.6% of the subscription rights to participate in the rights offering (the "Rights Offering") through which the Company offered $550 million of the First Lien Notes, which includes the backstop premium;
•Holders of the Senior Notes who participated in the Rights Offering received their pro ratashare of approximately 29.3%, or 21,975,000, of Common Shares, and senior noteholders who agreed to backstop the Rights Offering received their pro rata share of approximately 2.63%, or 1,975,500 of Common Shares and approximately $48.8 million in First Lien Notes as a backstop premium;
•Certain Revolving Credit Facility lenders ("RCF Lenders") who participated in the Rights Offering received their pro rata share of approximately 0.7%, or 525,000 Common Shares, RCF Lenders who agreed to backstop the Rights Offering received their pro rata share of 0.07%, or 49,500 of Common Shares and approximately $1.2 million in First Lien Notes as a backstop premium;
•Senior noteholders, solely with respect to Pride International LLC's 6.875% senior notes due 2020 and 7.875% senior notes due 2040, Ensco International 7.20% Debentures due 2027, and the 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, received an aggregate cash payment of $26.0 million in connection with settlement of certain alleged claims against the Company;
•The two RCF Lenders who chose to participate in the Rights Offering received their pro rata share of (1) 5.3%, or 4,005,000 of Common Shares (2) approximately 2.427% of the First Lien Notes (and associated Common Shares), (3) $7.8 million in cash, and (4) their pro rata share of the backstop premium. The RCF Lenders who entered into the amended restructuring support agreement and elected not to participate in the Rights Offering received their pro rata share of (1) 22.980%, or 17,235,000 of Common Shares and (2) $96.1 million in cash;
•Holders of general unsecured claims will receive payment in full within ninety days after the later of (a) the Effective Date and (b) the date such claim comes due;
•375,000 Common Shares were issued and $5.0 million was paid to Daewoo Shipbuilding & Marine Engineering Co., Ltd (the "Shipyard");
•Legacy Valaris Class A ordinary shares were cancelled and holders received 5,645,161 in Warrants exercisable for one Common Share per Warrant at initial exercise price of $131.88 per Warrant, in each case as may be adjusted from time to time pursuant to the applicable warrant agreement. The Warrants are exercisable for a period of seven years and will expire on April 29, 2028;
•All equity-based awards of Legacy Valaris that were outstanding were cancelled;
•On the Effective Date, Valaris entered into a registration rights agreement with certain parties who received Common Shares;
•On the Effective Date, Valaris entered into a registration rights agreement with certain parties who received First Lien Notes; and
•There were 0 borrowings outstanding against our debtor-in-possession ("DIP") facility and there were no DIP claims that were not due and payable on, or that otherwise survived, the Effective Date. The DIP Credit Agreement terminated on the Effective Date.
Management Incentive Plan
In accordance with the plan of reorganization, Valaris adopted the Valaris Limited 2021 Management Incentive Plan (the “MIP”) as of the Effective Date and authorized and reserved 8,960,573 Common Shares for issuance pursuant to equity incentive awards to be granted under the MIP, which may be in the form of incentive stock options, nonstatutory stock options, restricted stock, restricted stock units, stock appreciation rights, dividend equivalents and cash awards or any combination thereof.
Liabilities Subject to Compromise
The Debtors' pre-petition unsecured senior notes and related unpaid accrued interest as of the Petition Date were classified as Liabilities Subject to Compromise on our Condensed Consolidated Balance Sheets as of December 31, 2020. The liabilities were reported at the amounts expected to be allowed as claims by the Bankruptcy Court.
Liabilities subject to compromise at December 31, 2020 (Predecessor) consisted of the following (in millions):
| | | | | |
| |
6.875% Senior notes due 2020 | $ | 122.9 | |
4.70% Senior notes due 2021 | 100.7 | |
4.875% Senior notes due 2022 | 620.8 | |
3.00% Exchangeable senior notes due 2024 | 849.5 | |
4.50% Senior notes due 2024 | 303.4 | |
4.75% Senior notes due 2024 | 318.6 | |
8.00% Senior notes due 2024 | 292.3 | |
5.20% Senior notes due 2025 | 333.7 | |
7.375% Senior notes due 2025 | 360.8 | |
7.75% Senior notes due 2026 | 1,000.0 | |
7.20% Debentures due 2027 | 112.1 | |
7.875% Senior notes due 2040 | 300.0 | |
5.40% Senior notes due 2042 | 400.0 | |
5.75% Senior notes due 2044 | 1,000.5 | |
5.85% Senior notes due 2044 | 400.0 | |
Amounts drawn under the Revolving Credit Facility | 581.0 | |
Accrued Interest on Senior Notes and Revolving Credit Facility | 203.5 | |
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.
The contractual interest expense on the outstanding Senior Notes and the Revolving Credit Facility was in excess of recorded interest expense by $32.6 million and $132.9 million for the one month and four months ended April 30, 2021, respectively. This excess contractual interest was not included as interest expense on our Condensed Consolidated Statements of Operations, as we had discontinued accruing interest on the Predecessor's Senior Notes and Revolving Credit Facility subsequent to the Petition Date. The Predecessor discontinued making interest payments on our unsecured senior notes beginning in June 2020.
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 two months ended June 30, 2021 (Successor) and one month and four months ended April 30, 2021 (Predecessor). These costs include professional advisory service fees pertaining to the Chapter 11 Cases, contract items related to rejecting certain operating leases ("Contract items") and the effects of the emergence from bankruptcy, including the application of fresh start accounting.
The components of reorganization items, net were as follows (in millions):
| | | | | | | | | | | | | | | | | | | | |
| | Successor | | Predecessor |
| | Two Months Ended June 30, 2021 | | One Month Ended April 30, 2021 | | Four Months Ended April 30, 2021 |
| | | | | | |
| | | | | | |
| Professional fees | | $ | 5.6 | | | $ | 45.6 | | | $ | 93.4 | |
| Contract items | | (1.5) | | | 0 | | | 3.9 | |
| Reorganization items (fees) | | 4.1 | | | 45.6 | | | 97.3 | |
| | | | | | |
| | | | | | |
| Contract items | | 0 | | | 0 | | | .5 | |
| Backstop premium | | 0 | | | 30.0 | | | 30.0 | |
| Gain on settlement of liabilities subject to compromise | | 0 | | | (6,139.0) | | | (6,139.0) | |
| Issuance of Common Shares for backstop premium | | 0 | | | 29.1 | | | 29.1 | |
| Issuance of Common Shares to the Shipyard | | 0 | | | 5.4 | | | 5.4 | |
| Write-off of unrecognized share-based compensation expense | | 0 | | | 16.0 | | | 16.0 | |
| Impact of newbuild contract amendments | | 0 | | | 350.7 | | | 350.7 | |
| Loss on fresh start adjustments | | 0 | | | 9,194.6 | | | 9,194.6 | |
| Reorganization items (non-cash) | | 0 | | | 3,486.8 | | | 3,487.3 | |
| | | | | | |
| Total reorganization items, net | | $ | 4.1 | | | $ | 3,532.4 | | | $ | 3,584.6 | |
| | | | | | |
| Reorganization items (fees) unpaid | | $ | 2.2 | | | $ | 12.2 | | | $ | 38.3 | |
| Reorganization items (fees) paid | | $ | 1.9 | | | $ | 33.4 | | | $ | 59.0 | |
Note 3 -Fresh Start Accounting
Applicability of Fresh Start Accounting
Upon emergence from bankruptcy, we qualified for and applied fresh start accounting, which resulted in the Company becoming a new entity for financial reporting purposes because (1) the holders of the then existing Class A ordinary shares of the Predecessor received less than 50 percent of the new common shares of the Successor outstanding upon emergence and (2) the reorganization value of the Company’s assets immediately prior to confirmation of the plan of reorganization was less than the total of all post-petition liabilities and allowed claims.
The reorganization value derived from the range of enterprise values associated with the plan of reorganization was allocated to the Company’s identifiable tangible and intangible assets and liabilities based on their fair values (except for deferred income taxes). The amount of deferred income taxes recorded was determined in accordance with the applicable income tax accounting standard. The April 30, 2021 fair values of the Company’s assets and liabilities differ materially from their recorded values as reflected on the historical balance sheets.
Reorganization Value
The reorganization value represents the fair value of the Successor's total assets and was derived from the enterprise value associated with the plan of reorganization, which represents the estimated fair value of an entity's long-term debt and equity less unrestricted cash upon emergence from chapter 11. As set forth in the disclosure statement and approved by the bankruptcy court, third-party valuation advisors estimated the enterprise value to be between $1,860.0 million and $3,145.0 million. The enterprise value range of the reorganized Debtors was determined primarily by using a discounted cash flow analysis. The value agreed in the plan of reorganization is indicative of an enterprise value at the low end of this range, or $1,860.0 million.
The following table reconciles the enterprise value to the estimated fair value of Successor Common Shares as of the Effective Date (in millions, except per share value):
| | | | | |
| April 30, 2021 |
Enterprise Value | $ | 1,860.0 | |
Plus: Cash and cash equivalents | 607.6 | |
Less: Fair value of debt | (544.8) | |
Less: Warrants | (16.4) | |
Less: Noncontrolling interest | 1.1 | |
Less: Pension and other post retirement benefits liabilities | (189.0) | |
Less: Adjustments not contemplated in Enterprise Value | (639.0) | |
Fair value of Successor Common Shares | $ | 1,079.5 | |
Shares issued upon emergence | 75 | |
Per share value | $ | 14.39 | |
The following table reconciles the enterprise value to the reorganization value as of the Effective Date (in millions):
| | | | | |
| April 30, 2021 |
Enterprise Value | $ | 1,860.0 | |
Plus: Cash and cash equivalents | 607.6 | |
Plus: Non-interest bearing current liabilities | 346.0 | |
Less: Adjustments not contemplated in Enterprise Value | (218.0) | |
Reorganization value of Successor assets | $ | 2,595.6 | |
Adjustments not contemplated in Enterprise Value represent certain obligations of the Successor that were either not contemplated or contemplated in a different amount in the forecasted cash flows of the enterprise valuation performed by third-party valuation advisors that had they incorporated those anticipated cash flows into their analysis, the resulting valuation would have been different. For the reconciliation of Reorganization value of Successor assets, this item includes certain tax balances, contract liabilities, as well as an adjustment for the fair value of pension obligations. The reconciliation to Successor Common Share value includes these same reconciling items as well as other current and non-current liabilities of the Successor at the emergence.
The enterprise value and corresponding implied equity value are dependent upon achieving the future financial results set forth in the valuation utilizing assumptions regarding future day rates, utilization, operating costs and capital requirements as of the emergence date. All estimates, assumptions, valuations and financial projections, including the fair value adjustments, the enterprise value and equity value projections, are inherently subject to significant uncertainties and the resolution of contingencies beyond our control. Accordingly, there is no assurance that the estimates, assumptions, valuations or financial projections will be realized, and actual results could vary materially.
Valuation Process
The fair values of the Company's principal assets and liabilities including property, plant and equipment as well as our 50% equity interest in Saudi Aramco Rowan Offshore Drilling Company ("ARO") and our notes receivable from ARO, the First Lien Notes, pensions and Warrants were estimated with the assistance of third-party valuation advisors.
Property, Plant and Equipment
The valuation of the Company’s drilling rigs was estimated by using an income approach 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, reactivation costs and capital requirements. In developing these assumptions, forecasted day rates and utilization took into account current market conditions and our anticipated business outlook. The cash flows were discounted at our weighted average cost of capital ("WACC"), which was derived from a blend of our after-tax cost of debt and our cost of equity, and computed using public share price information for similar offshore drilling market participants, certain U.S. Treasury rates and certain risk premiums specific to the Company.
Our remaining property and equipment including owned real estate and other equipment was valued using a cost approach, in which the estimated replacement cost of the assets was adjusted for physical depreciation and obsolescence, where applicable, to arrive at estimated fair value.
The estimated fair value of our property and equipment includes an adjustment to reconcile to our reorganization value.
Notes Receivable from ARO
The fair value of the long-term notes receivable from ARO was estimated using an income approach to value the forecasted cash flows attributed to the note receivable using a discount rate based on a comparable yield with a country-specific risk premium.
Investment in ARO
We estimated the fair value of the equity investment in ARO primarily by applying an income approach, using projected discounted cash flows of the underlying assets, a risk-adjusted discount rate and an estimated effective income tax rate.
First Lien Notes
The fair value of the First Lien Notes was determined to approximate the par value based on third-party valuation advisors’ analysis of the Company’s collateral coverage, financial metrics, and interest rate for the First Lien Notes relative to market rates of recent placements of a similar term for industry participants with similar credit risk.
Pensions
Our pension and other postretirement benefit liabilities and costs are based upon actuarial computations that reflect our assumptions about future events, including long-term asset returns, interest rates, annual compensation increases, mortality rates and other factors. Upon emergence, our pension and other post retirement plans were remeasured as of the Effective Date. Key assumptions at the Effective Date included (1) a weighted average discount rate of 2.81% to determine pension benefit obligations and (2) an expected long-term rate of return on pension plan assets of 6.03% to determine net periodic pension cost.
Warrants
The fair value of the Warrants was determined using an option pricing model considering the contractual terms of the Warrant issuance. The key market data assumptions for the option pricing model are the estimated volatility and the risk-free rate. The volatility assumption was estimated using market data for offshore drilling market participants with consideration for differences in leverage. The risk-free rate assumption was based on U.S. Treasury Constant Maturity rates with a comparable term.
Condensed Consolidated Balance Sheet
The adjustments included in the following condensed consolidated balance sheet reflect the effects of the transactions contemplated by the plan of reorganization and executed by the Company on the Effective Date (reflected in the column “Reorganization Adjustments”), and fair value and other required accounting adjustments resulting from the adoption of fresh start accounting (reflected in the column “Fresh Start Accounting Adjustments”). The explanatory notes provide additional information with regard to the adjustments recorded.
| | | | | | | | | | | | | | | | | | | | | | | |
| As of April 30, 2021 |
| Predecessor | | Reorganization Adjustments | | Fresh Start Accounting Adjustments | | Successor |
| | | | | | | |
| ASSETS |
| CURRENT ASSETS | | | | | | | |
| Cash and cash equivalents | $ | 280.2 | | | $ | 327.4 | | (a) | $ | 0 | | | $ | 607.6 | |
| Restricted cash | 45.7 | | | 42.7 | | (b) | 0 | | | 88.4 | |
| Accounts receivable, net | 425.9 | | | 0 | | | 0 | | | 425.9 | |
| Other current assets | 370.1 | | | 1.5 | | (c) | (281.1) | | (o) | 90.5 | |
| Total current assets | 1,121.9 | | | 371.6 | | | (281.1) | | | 1,212.4 | |
| | | | | | | |
| | | | | | | |
| PROPERTY AND EQUIPMENT, NET | 10,026.4 | | | (417.6) | | (d) | (8,699.7) | | (p) | 909.1 | |
| LONG-TERM NOTES RECEIVABLE FROM ARO | 442.7 | | | 0 | | | (214.4) | | (q) | 228.3 | |
| INVESTMENT IN ARO | 123.9 | | | 0 | | | (43.4) | | (r) | 80.5 | |
| OTHER ASSETS | 166.4 | | | (10.0) | | (e) | 8.9 | | (s) | 165.3 | |
| | $ | 11,881.3 | | | $ | (56.0) | | | $ | (9,229.7) | | | $ | 2,595.6 | |
| LIABILITIES AND SHAREHOLDERS' EQUITY |
| CURRENT LIABILITIES | | | | | | | |
| Accounts payable - trade | $ | 161.5 | | | $ | 13.1 | | (f) | $ | (0.5) | | (t) | $ | 174.1 | |
| Accrued liabilities and other | 290.7 | | | (12.4) | | (g) | (61.8) | | (u) | 216.5 | |
| Total current liabilities | 452.2 | | | 0.7 | | | (62.3) | | | 390.6 | |
| LONG-TERM DEBT | 0 | | | 544.8 | | (h) | 0 | | | 544.8 | |
| OTHER LIABILITIES | 706.2 | | | (55.2) | | (i) | (85.6) | | (v) | 565.4 | |
| Total liabilities not subject to compromise | 1,158.4 | | | 490.3 | | | (147.9) | | | 1,500.8 | |
| LIABILITIES SUBJECT TO COMPROMISE | 7,313.7 | | | (7,313.7) | | (j) | 0 | | | 0 | |
| COMMITMENTS AND CONTINGENCIES | | | | | | | |
| VALARIS SHAREHOLDERS' EQUITY | | | | | | | |
| Predecessor Class A ordinary shares | 82.5 | | | (82.5) | | (k) | 0 | | | 0 | |
| Predecessor Class B ordinary shares | 0.1 | | | (0.1) | | (k) | 0 | | | 0 | |
| Successor common shares | 0 | | | 0.8 | | (l) | 0 | | | 0.8 | |
| Successor stock warrants | 0 | | | 16.4 | | (m) | 0 | | | 16.4 | |
| Predecessor additional paid-in capital | 8,644.0 | | | (8,644.0) | | (k) | 0 | | | 0 | |
| Successor additional paid-in capital | 0 | | | 1,078.7 | | (l) | 0 | | | 1,078.7 | |
| Retained deficit | (5,147.4) | | | 14,322.6 | | (n) | (9,175.2) | | (w) | 0 | |
| Accumulated other comprehensive loss | (93.4) | | | 0 | | | 93.4 | | (x) | 0 | |
| Predecessor treasury shares | (75.5) | | | 75.5 | | (k) | 0 | | | 0 | |
| Total Valaris shareholders' equity | 3,410.3 | | | 6,767.4 | | | (9,081.8) | | | 1,095.9 | |
| NONCONTROLLING INTERESTS | (1.1) | | | 0 | | | 0 | | | (1.1) | |
| Total equity | 3,409.2 | | | 6,767.4 | | | (9,081.8) | | | 1,094.8 | |
| | $ | 11,881.3 | | | $ | (56.0) | | | $ | (9,229.7) | | | $ | 2,595.6 | |
Reorganization Adjustments
(a)Cash
Represents the reorganization adjustments (in millions):
| | | | | |
Receipt of cash for First Lien Notes | $ | 500.0 | |
Loan proceeds from backstop lenders | 20.0 | |
Funds received for liquidation of rabbi trust related to certain employee benefits | 17.6 | |
PaymentsPayments to Predecessor Creditors | (129.9) | |
Transfer of funds for payment of certain professional fees to escrow account | (42.7) | |
Payment for certain professional services fees | (29.0) | |
Various other | (8.6) | |
| $ | 327.4 | |
(b)Restricted cash
Reflects the reorganization adjustment to record the transfer of cash for payment of certain professional fees to restricted cash, which will be held in escrow until billings from professionals have been received and reconciled at which time the funds in the account will be released.
(c)Other current asset
Reflects certain prepayments incurred upon emergence.
(d)Property and Equipment, net
Reflects the reorganization adjustment to remove $417.6 million of work-in-process related to the Newbuild Rigs. These values have been removed from property and equipment, net, based on the terms of the amended agreements with the Shipyard. As a result of the option to take delivery, we removed the historical work-in-process balances from the balance sheet.
(e)Other assets
Represents the reorganization adjustments (in millions):
| | | | | |
Liquidation of rabbi trust related to certain employee benefits | $ | (17.6) | |
Elimination of right-of-use asset associated with Newbuild Rigs | (5.5) | |
Fair value of options to purchase Newbuild Rigs | 13.1 | |
| $ | (10.0) | |
Our supplemental executive retirement plans (the "SERPs") are non-qualified plans that provided eligible employees an opportunity to defer a portion of their compensation for use after retirement. The SERPs were frozen to the entry of new participants in November 2019 and to future compensation deferrals as of January 1, 2020. Upon emergence, assets previously held in a rabbi trust maintained for the SERP were liquidated and the SERPs were amended.
In accordance with the amended agreement with the Shipyard, our leases were terminated and we have eliminated the historical right-of-use asset associated with the berthing locations of VALARIS DS-13 and VALARIS DS-14.
Additionally, upon effectiveness of the plan of reorganization, the amended agreement with the Shipyard provides the Company with the option to purchase the Newbuild Rigs. The reorganization adjustments include a Contract Intangible asset that reflects the fair value of the option to purchase the Newbuild Rigs and embedded feature related to the ability, under the amended agreements with the Shipyard, for the equity issued pursuant to this arrangement to be put to the Company for $8.0 million of consideration for each rig, should we choose to take delivery.
(f)Accounts payable - trade
Reflects the following reorganization adjustments (in millions):
| | | | | |
Professional fees incurred upon emergence | $ | 26.1 | |
Payment of professional fees incurred prior to emergence | (12.6) | |
Payment of certain accounts payable incurred prior to emergence | (0.4) | |
| $ | 13.1 | |
(g)Accrued liabilities and other
Reflects the following reorganization adjustments (in millions):
| | | | | |
Elimination of lease liabilities associated with Newbuild Rigs | $ | (5.0) | |
Elimination of accrued post-petition holding costs associated with Newbuild Rigs | (4.1) | |
Payment of certain accrued liabilities incurred prior to emergence | (3.3) | |
| $ | (12.4) | |
In accordance with the amended agreement with the Shipyard, our leases were terminated and we have eliminated the historical lease liability associated with the berthing locations of VALARIS DS-13 and VALARIS DS-14. Accrued post-petition holding costs have also been eliminated as a result of the amendments executed upon emergence. Additionally, reorganization adjustments to accrued liabilities and other includes an amount primarily related to payment of professional fees incurred prior to emergence.
(h)Long-term debt
Reflects the reorganization adjustment to record the issuance of the $550.0 million aggregate principal amount of First Lien Notes and debt issuance costs of $5.2 million.
(i)Other liabilities
Reflects the following reorganization adjustments (in millions):
| | | | | |
Elimination of construction contract intangible liabilities associated with Newbuild Rigs | $ | (49.9) | |
Elimination of accrued post-petition holding costs associated with Newbuild Rigs | (4.7) | |
Elimination of lease liabilities associated with Newbuild Rigs | (0.6) | |
| |
| $ | (55.2) | |
The reorganization adjustments to other liabilities primarily relate to the elimination of construction contract intangibles associated with the Newbuild Rigs. These construction contract intangible liabilities were recorded in purchase accounting for the original contracting entity. As the amended contract is structured as an
option whereby we have the right, not the obligation to take delivery of the rigs, there is no longer an intangible liability associated with the contracts and it has been eliminated from the financial statements.
We have eliminated the historical lease liability associated with the berthing locations of VALARIS DS-13 and VALARIS DS-14 and accrued post-petition holding costs as described in (g) above.
(j) Liabilities subject to compromise
Reflects the following reorganization adjustments (in millions):
| | | | | |
| |
| |
| |
| |
| |
| |
| |
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| |
| |
| |
| |
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Settlement of liabilities subject to compromise | $ | 7,313.7 | |
Issuance of common stock to Predecessor creditors | (721.0) | |
Issuance of common stock to backstop parties | (323.8) | |
Payment to Predecessor creditors | (129.9) | |
Gain on settlement of liabilities subject to compromise | $ | 6,139.0 | |
(k)Predecessor ordinary shares, additional paid-in capital and treasury shares
Represents the cancellation of the Predecessor's common shares of $82.6 million, additional paid-in capital of $8,644.0 million and treasury stock of $75.5 million.
(l)Successor common shares and additional paid-in capital
Represents par value of 75 million new Common Shares of $0.8 million and capital in excess of par value of $1,078.7 million.
(m)Successor stock warrants
On the Effective Date and pursuant to the plan of reorganization, Valaris issued an aggregate of 5.6 million Warrants exerciseable for up to an aggregate of 5.6 million Common Shares to former holders of Legacy Valaris's equity interests. The fair value of the Warrants as of the Effective Date was $16.4 million.
(n)Retained deficit
Represents the reorganization adjustments to total equity as follows (in millions):
| | | | | |
Gain on settlement of liabilities subject to compromise | $ | (6,139.0) | |
Issuance of Common Shares for backstop premium | 29.1 | |
Issuance of Common Shares to the Shipyard | 5.4 | |
Write-off of unrecognized share-based compensation expense | 16.0 | |
Professional fees and success fees | 35.9 | |
Backstop premium | 30.0 | |
Impact of newbuild contract amendments | 350.7 | |
Reorganization items, net | (5,671.9) | |
Cancellation of Predecessor common shares | (82.6) | |
Cancellation of Predecessor treasury shares | 75.5 | |
Cancellation of Predecessor additional paid in capital | (7,856.4) | |
Cancellation of equity component of Predecessor convertible notes | (220.0) | |
Cancellation of Predecessor cash and equity compensation plans | (583.6) | |
Fair value of Warrants | 16.4 | |
| $ | (14,322.6) | |
Fresh Start Adjustments
(o) Other current assets
Reflects the fresh start adjustments to record the estimated fair value of other current assets as follows (in millions):
| | | | | |
Elimination of materials and supplies | $ | (260.8) | |
Elimination of historical deferred contract drilling expenses | (20.3) | |
| $ | (281.1) | |
Primarily reflects the fresh start adjustment to eliminate the Valaris historical balance for materials and supplies as the result of a change in accounting policy upon emergence.
The fresh start adjustment for the elimination of historical deferred contract drilling expenses primarily relates to deferred mobilization costs, deferred contract preparation costs. and deferred certification costs. Costs incurred for mobilization and contract preparation prior to the commencement of drilling services are deferred and subsequently amortized over the term of the related drilling contract. Additionally, 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. These deferred costs have no future economic benefit to Valaris and are eliminated from the fresh start financial statements.
(p) Property and equipment, net
Reflects the fresh start adjustments to historical amounts to record the estimated fair value of property and equipment.
(q) Long-term notes receivable from ARO
Reflects the fresh start adjustment to record the estimated fair value of the long-term notes receivable from ARO. The fair value of the long-term notes receivable from ARO was estimated using an income approach to value the forecasted cash flows attributed to the note receivable using a discount rate based on comparable yield with a country-specific risk premium.
(r) Investment in ARO
Reflects the fresh start adjustment to record the estimated fair value of the equity investment in ARO.
(s) Other assets
Reflects the fresh start adjustments to record the estimated fair value of other assets as follows (in millions):
| | | | | |
Deferred tax impacts of certain fresh start adjustments | $ | 21.1 | |
Fair value of contracts with customers | 8.5 | |
Fair value adjustments to right-of-use assets | 0.4 | |
Elimination of historical deferred contract drilling expenses | (16.5) | |
Elimination of other deferred costs | (4.6) | |
| $ | 8.9 | |
The fresh start adjustment for deferred income tax assets represents the estimated incremental deferred income taxes, which reflects the tax effect of the differences between the estimated fair value of certain assets and liabilities recorded under fresh start accounting and the carryover tax basis of those assets and liabilities.
The fresh start adjustment to record the estimated fair value of contracts with customers represents the intangible assets recognized for firm customer contracts in place at the balance sheet date that have favorable contract terms as compared to current market day rates for comparable drilling rigs. The various factors considered in the adjustment are (1) the contracted day rate for each contract, (2) the remaining term of each contract, (3) the rig class and (4) the market conditions for each respective rig class at the emergence date. The intangible assets are computed based on the present value of the difference in cash inflows over the remaining contract term as compared to a hypothetical contract with the same remaining term at an estimated current market day rate using a risk-adjusted discount rate and an estimated effective income tax rate. This balance will be amortized to operating revenues over the respective remaining contract terms on a straight-line basis.
The fresh start adjustment to right-of-use assets reflects the remeasuring our operating leases as of the emergence date. Certain operating leases had unfavorable terms as of the emergence date, and as a result the right-of-use asset for such leases does not equal the lease liability upon emergence.
The fresh start adjustment to eliminate historical deferred contract drilling expenses reflects the noncurrent portion of historical deferred contract drilling expenses described in (n) above as well as the elimination of customer contract intangibles previously recorded in purchase accounting.
The fresh start adjustments to eliminate other deferred costs reflect non-operational deferred costs that have no future economic benefit to Valaris.
(t) Accounts payable - trade
The fresh start adjustment to accounts payable trade reflects the write off of certain deferred amounts related to our operating leases. This value was eliminated through the remeasurement of our leases as of the emergence date.
(u)Accrued liabilities and other
Reflects the fresh start adjustments to record the estimated fair value of current liabilities as follows (in millions):
| | | | | |
Elimination of customer payable balance | $ | (36.8) | |
Elimination of historical deferred revenues | (25.9) | |
Fair value of contracts with customers | 0.5 | |
Fair value adjustment to lease liabilities | 0.4 | |
| $ | (61.8) | |
The fresh start adjustment to eliminate the customer payable balance is related to a fresh start adjustment made to present the balance on a net basis.
The fresh start adjustment to eliminate historical deferred revenues is primarily related to amounts previously received for the reimbursement for capital upgrades, upfront contract deferral fees and mobilization. Such amounts are deferred and subsequently amortized over the term of the related drilling contract. The deferred revenue does not represent future performance obligations of Valaris and are eliminated as fresh accounting adjustments.
The fresh start adjustment to record the estimated fair value of contracts with customers reflects the intangible liabilities recognized for firm customer contracts that have unfavorable contract terms as compared to current market day rates for comparable assets. The various factors considered in the adjustment are (1) the contracted day rate for each contract, (2) the remaining term of each contract, (3) the rig class and (4) the market conditions for each respective rig class at the emergence date. The intangible liabilities are computed based on the present value of the difference in cash inflows over the remaining contract term as compared to a hypothetical contract with the same remaining term at an estimated current market day rate using a risk-adjusted discount rate and an estimated effective income tax rate. This balance will be amortized to operating revenues over the respective remaining contract terms on a straight-line basis.
The fresh start adjustment to lease liabilities reflects the remeasuring of our operating leases as of the emergence date.
(v)Other liabilities
Reflects the fresh start adjustments to record the estimated fair value of other liabilities as follows (in millions):
| | | | | |
Adjustment to fair value of pension and other post-retirement plan liabilities | $ | (82.7) | |
Elimination of historical deferred revenue | (5.9) | |
Deferred tax impacts of certain fresh start adjustments | 1.7 | |
Fair value adjustments to lease liabilities | 1.1 | |
Fair value adjustments to other liabilities | 0.2 | |
| $ | (85.6) | |
The fresh start adjustment to fair value pension and other post-retirement plan liabilities results from the remeasurement of the pension and other post-retirement benefit plans at the emergence date.
The fresh start adjustment to eliminate deferred revenues reflects the noncurrent portion of deferred revenues described in (t) above.
The fresh start adjustment for deferred income tax liabilities represents the estimated incremental deferred taxes, which reflects the tax effect of the differences between the estimated fair value certain assets and liabilities recorded under fresh start accounting and the carryover tax basis of those assets and liabilities.
The fresh start adjustment to lease liabilities reflects the remeasuring of our operating leases as of the Effective Date.
(w)Retained Deficit
Reflects the fresh start adjustments to retained deficit as follows (in millions):
| | | | | |
Fair value adjustments to prepaid and other current assets | $ | (281.1) | |
Fair value adjustments to property | (8,699.7) | |
Fair value of intangible assets | 8.5 | |
Fair value adjustment to investment in ARO | (43.4) | |
Fair value adjustment to note receivable from ARO | (214.4) | |
Fair value adjustments to other assets | (20.7) | |
Fair value adjustments to other current liability | 62.8 | |
Fair value of intangible liabilities | (0.5) | |
Fair value adjustment to other liabilities | 87.3 | |
Elimination of Predecessor accumulated other comprehensive loss | (93.4) | |
Total fresh start adjustments included in reorganization items, net | $ | (9,194.6) | |
Tax impact of fresh start adjustments | 19.4 | |
| $ | (9,175.2) | |
(x)Accumulated other comprehensive loss
Reflects the fresh start adjustments for the elimination of Predecessor accumulated other comprehensive loss through reorganization items, net.
Note 42 -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 contracts contain a lease component and we have elected to apply the practical expedient provided under Accounting Standards Codification ("ASC") 842 to not separate the lease and non-lease components and apply the revenue recognition guidance in ASU No. 2014-09, "Revenue from Contracts with Customers (Topic 606)." 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 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 "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 June 30, 2021March 31, 2022 was between approximately one1 month and three3.5 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 are 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 operatingOperating revenues. The costs incurred in connection with the mobilization and demobilization of equipment and personnel are included in contractContract 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 operatingOperating revenues. Costs incurred for capital upgrades are capitalized and depreciated over the useful life of the asset.
Contract Assets and Liabilities
Contract assets represent amounts recognized as revenue but for which the right to invoice the customer is dependent upon our future performance. Once the previously recognized revenue is invoiced, the corresponding contract asset, or a portion thereof, is transferred to accounts receivable.
Contract liabilities generally represent fees received for mobilization, capital upgrades 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 otherOther current assets and accruedAccrued liabilities and other, respectively, and noncurrent contract assets and liabilities are included in otherOther assets and otherOther liabilities, respectively, on our Condensed Consolidated Balance Sheets.
As of June 30, 2021 and December 31, 2020, we have a contract liability with 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 5 – 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):
| | | Successor | | | Predecessor | |
| | | June 30, 2021 | | | December 31, 2020 | | March 31, 2022 | | | December 31, 2021 |
| Current contract assets | Current contract assets | $ | 3.1 | | | | $ | 1.4 | | Current contract assets | $ | 3.6 | | | | $ | 0.3 | |
| Noncurrent contract assets | Noncurrent contract assets | $ | 0 | | | | $ | .4 | | Noncurrent contract assets | $ | 0.1 | | | | $ | — | |
| Current contract liabilities (deferred revenue) | Current contract liabilities (deferred revenue) | $ | 35.2 | | | | $ | 57.6 | | Current contract liabilities (deferred revenue) | $ | 56.3 | | | | $ | 45.8 | |
| Noncurrent contract liabilities (deferred revenue) | Noncurrent contract liabilities (deferred revenue) | $ | 10.2 | | | | $ | 14.3 | | Noncurrent contract liabilities (deferred revenue) | $ | 9.7 | | | | $ | 10.8 | |
Changes in contract assets and liabilities during the period are as follows (in millions):
| | | | | | | | | | | |
| | Contract Assets | | Contract Liabilities |
| Balance as of December 31, 2020 (Predecessor) | $ | 1.8 | | | $ | 71.9 | |
| Revenue recognized in advance of right to bill customer | 2.3 | | | — | |
| Increase due to cash received | — | | | 10.2 | |
| Decrease due to amortization of deferred revenue that was included in the beginning contract liability balance | — | | | (14.8) | |
| | | |
| Decrease due to transfer to receivables during the period | (1.6) | | | — | |
| Fresh start accounting revaluation | (.3) | | | (31.6) | |
| Balance as of April 30, 2021 (Predecessor) | $ | 2.2 | | | $ | 35.7 | |
| | | |
| | | |
| Balance as of May 1, 2021 (Successor) | $ | 2.2 | | | $ | 35.7 | |
| Revenue recognized in advance of right to bill customer | .9 | | | — | |
| Increase due to cash received | — | | | 10.3 | |
| | | |
| Decrease due to amortization of deferred revenue that was added during the period | — | | | (.6) | |
| | | |
| Balance as of June 30, 2021 (Successor) | $ | 3.1 | | | $ | 45.4 | |
| | | | | | | | | | | |
| | Contract Assets | | Contract Liabilities |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Balance as of December 31, 2021 | $ | 0.3 | | | $ | 56.6 | |
| Revenue recognized in advance of right to bill customer | 3.4 | | | — | |
| Increase due to cash received | — | | | 22.3 | |
| Decrease due to amortization of deferred revenue that was included in the beginning contract liability balance | — | | | (12.1) | |
| Decrease due to amortization of deferred revenue added during the period | — | | | (0.8) | |
| | | |
| Balance as of March 31, 2022 | $ | 3.7 | | | $ | 66.0 | |
Deferred Contract Costs
Costs incurred for upfront rig mobilizations and certain contract preparations are attributable to our future performance obligation under each respective drilling contract. These costs are deferred and amortized on a straight-line basis over the contract term. Demobilization costs are recognized as incurred upon contract completion. Costs associated with the mobilization of equipment and personnel to more promising market areas without contracts are expensed as incurred. Deferred contract costs were included in otherOther current assets and otherOther assets on our Condensed Consolidated Balance Sheets and totaled $20.8$37.2 million and $13.8$31.4 million as of June 30, 2021
(Successor)March 31, 2022 and December 31, 2020 (Predecessor),2021, respectively. For the Successor, during the twothree months ended June 30,March 31, 2022, amortization of such costs totaled $11.7 million. For the Predecessor, during the three months ended March 31, 2021, amortization of such costs totaled $3.6$5.8 million. For the Predecessor, during the one month and four months ended April 30, 2021, amortization of such costs totaled $1.8 million and $7.6 million, respectively. During the three and six months ended June 30, 2020, amortization of such costs for the Predecessor totaled $17.5 million and $28.9 million, respectively.
Deferred Certification Costs
We must obtain certifications from various regulatory bodies in order to operate our drilling rigs and must maintain such certifications through periodic inspections and surveys. The costs incurred in connection with maintaining such certifications, including inspections, tests, surveys and drydock, as well as remedial structural work and other compliance costs, are deferred and amortized on a straight-line basis over the corresponding certification periods. Deferred regulatory certification and compliance costs were included in otherOther current assets and otherOther assets on our Condensed Consolidated Balance Sheets and totaled $1.3$7.6 million and $8.4$3.3 million as of June 30, 2021 (Successor)March 31, 2022 and December 31, 2020 (Predecessor),2021, respectively. For the Successor, during the twothree months ended June 30, 2021,March 31, 2022, amortization of thesesuch costs totaled $0.6$0.3 million. For the Predecessor, during the one month and fourthree months ended April 30,March 31, 2021, amortization of these cost totaled $0.5 million and $3.1 million, respectively. During the three and six months ended June 30, 2020, amortization of such costs for the Predecessor totaled $2.6 million and $5.7 million, respectively.million.
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 operatingOperating revenues and contractContract drilling expense, respectively, with the exception of the contract liabilities related to our Lease Agreementsbareboat charter arrangements with ARO which would not be contractually payable until the end of the lease term or termination, if sooner. ExpectedSee "Note 3- Equity Method Investment in ARO" for additional information on ARO and related arrangements. The expected future amortization for the Successor of our contract liabilities, or in the case of our contract liabilities related to our bareboat charter arrangements with ARO, the amount is reflected at the end of the lease term, and deferred costs recorded as of June 30, 2021March 31, 2022 is set forth in the table below (in millions): | | | | Remaining 2021 | | 2022 | | 2023 | | 2024 and Thereafter | | Total | | Remaining 2022 | | 2023 | | 2024 | | 2025 and Thereafter | | Total |
| Amortization of contract liabilities | Amortization of contract liabilities | $ | 33.7 | | | $ | 11.0 | | | $ | .7 | | | $ | 0 | | | $ | 45.4 | | Amortization of contract liabilities | $ | 54.6 | | | $ | 5.4 | | | $ | 3.8 | | | $ | 2.2 | | | $ | 66.0 | |
| Amortization of deferred costs | Amortization of deferred costs | $ | 14.0 | | | $ | 8.1 | | | $ | 0 | | | $ | 0 | | | $ | 22.1 | | Amortization of deferred costs | $ | 26.6 | | | $ | 15.4 | | | $ | 2.8 | | | $ | — | | | $ | 44.8 | |
Note 53 -Equity Method Investment in ARO
Background
ARO is a company50/50 unconsolidated joint venture between the Company and Saudi Aramco that owns and operates offshore drilling rigs in Saudi Arabia, was formed and commenced operations in 2017 pursuant to the termsArabia. As 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.March 31, 2022, ARO owns 7 jackup rigs, has ordered 2 newbuild jackup rigs, and leases 98 rigs from us through bareboat charter arrangements (the "Lease Agreements") whereby substantially all operating costs are incurred by ARO. As of June 30, 2021,At March 31, 2022, all 9 of the leased rigs were operating under three-year drilling contracts, or related extensions, with Saudi Aramco. The seven7 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
ARO has plans to take all steps necessary to ensure that ARO purchasespurchase 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 $176.0 million,million. These newbuild rigs are expected to be delivered in the first or second quarter of 2023 and ARO is expected to place orders for delivery scheduledtwo additional newbuild jackups in 2022. The joint venture partners intendIn connection with these plans, we have a potential obligation to fund ARO for the newbuild jackup rigs to be financed out of available cash from ARO's operations and/orrigs. See "Note 11 - Contingencies" for additional information.
funds available from third-party debt financing. In the event ARO has insufficient cash from operations or is unable to obtain third-party financing, each partner may periodically be required to make additional capital contributions to ARO, up to a maximum aggregate contribution of $1.25 billion from each partner to fund the newbuild program. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, on a proportionate basis. The joint venture partners agreed in the shareholders' agreement that Saudi Aramco, as a customer, will provide drilling contracts to ARO in connection with the acquisition of the newbuild rigs. The initial contracts provided by Saudi Aramco for each of the newbuild rigs will be for an eight-year term. The day rate for the initial contracts for each newbuild rig will be determined using a pricing mechanism that targets a six-year payback period for construction costs on an EBITDA basis. The initial eight-year contracts will be followed by a minimum of another eight years of term, re-priced in three-year intervals based on a market pricing mechanism.
Upon establishment of ARO, Rowan 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 provided various services to ARO, and in return, ARO provided remuneration for those services. 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, depending 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 | | Six Months Ended | | Three Months Ended | |
| | June 30, 2021 | | June 30, 2020 | | June 30, 2021 | | June 30, 2020 | | March 31, 2022 | | March 31, 2021 | |
| Revenues | Revenues | | $ | 124.8 | | | $ | 146.0 | | | $ | 247.5 | | | $ | 286.3 | | Revenues | | $ | 111.3 | | | $ | 122.7 | | |
| Operating expenses | Operating expenses | | Operating expenses | | |
| Contract drilling (exclusive of depreciation) | Contract drilling (exclusive of depreciation) | | 92.7 | | | 112.5 | | | 179.0 | | | 220.8 | | Contract drilling (exclusive of depreciation) | | 84.2 | | | 86.3 | | |
| Depreciation | Depreciation | | 14.6 | | | 13.3 | | | 30.7 | | | 26.3 | | Depreciation | | 16.5 | | | 16.1 | | |
| General and administrative | General and administrative | | 4.3 | | | 7.1 | | | 7.3 | | | 15.4 | | General and administrative | | 5.2 | | | 3.0 | | |
| Operating income | Operating income | | 13.2 | | | 13.1 | | | 30.5 | | | 23.8 | | Operating income | | 5.4 | | | 17.3 | | |
| Other expense, net | Other expense, net | | 3.1 | | | 6.7 | | | 7.6 | | | 13.3 | | Other expense, net | | 3.3 | | | 4.5 | | |
| Provision (Benefit) for income taxes | | 1.9 | | | (.2) | | | 6.4 | | | .7 | | |
| Provision for income taxes | | Provision for income taxes | | 0.7 | | | 4.5 | | |
| Net income | Net income | | $ | 8.2 | | | $ | 6.6 | | | $ | 16.5 | | | $ | 9.8 | | Net income | | $ | 1.4 | | | $ | 8.3 | | |
| | | | | | | | | | | | | | |
| | March 31,
2022 | | December 31, 2021 |
| Cash and cash equivalents | | $ | 240.2 | | | $ | 270.8 | |
| Other current assets | | 179.5 | | | 135.0 | |
| Non-current assets | | 775.8 | | | 775.8 | |
| Total assets | | $ | 1,195.5 | | | $ | 1,181.6 | |
| | | | |
| Current liabilities | | $ | 92.9 | | | $ | 79.9 | |
| Non-current liabilities | | 957.9 | | | 956.7 | |
| Total liabilities | | $ | 1,050.8 | | | $ | 1,036.6 | |
| | | | | | | | | | | | | | |
| | June 30,
2021 | | December 31, 2020 |
| Cash and cash equivalents | | $ | 318.2 | | | $ | 237.7 | |
| Other current assets | | 81.7 | | | 120.9 | |
| Non-current assets | | 782.8 | | | 804.0 | |
| Total assets | | $ | 1,182.7 | | | $ | 1,162.6 | |
| | | | |
| Current liabilities | | $ | 74.9 | | | $ | 70.8 | |
| Non-current liabilities | | 950.3 | | | 950.8 | |
| Total liabilities | | $ | 1,025.2 | | | $ | 1,021.6 | |
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 equityEquity in earnings (losses) of ARO in our Condensed Consolidated Statements of Operations. ARO is a variable interest entity; however, we are not the primary beneficiary and therefore do not consolidate ARO. Judgments regarding our level of influence over ARO included considering key factors such as each partner's ownership interest, representation on the board of managers of ARO and ability to direct activities that most significantly impact ARO's economic performance, including the ability to influence policy-making decisions. Our investment in ARO would be assessed for impairment if there wereare 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 ofat both the Effective Date and the date we acquiredof our 50% interest on April 11, 2019 ("Investment Date").combination with our joint venture partner. We computed the difference between the fair value of ARO's net assets and the carrying value of those net assets in ARO's U.S. GAAP financial statements ("basis differences") on that date.each of these dates. These basis differences primarily relaterelated 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. Additionally, in fresh start accounting, we have recorded our investment in ARO at its estimated fair valueterms as of the date of emergence. Basis differences on that date primarily related to ARO's long-lived assets.measurement dates.
Basis differences are amortized over the remaining life of the assets or liabilities to which they relate and are recognized as an adjustment to the equityEquity in earnings (losses) 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):
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor |
| Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2020 |
| 50% interest in ARO net income | $ | 2.3 | | | | $ | 1.9 | | | $ | 3.3 | |
| Amortization of basis differences | 2.5 | | | | (.7) | | | (8.5) | |
| Equity in earnings (losses) of ARO | $ | 4.8 | | | | $ | 1.2 | | | $ | (5.2) | |
| | | Successor | | | Predecessor | | Successor | | | | Predecessor |
| | Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 | | Three Months Ended March 31, 2022 | | | | Three Months Ended March 31, 2021 |
| 50% interest in ARO net income | 50% interest in ARO net income | $ | 2.3 | | | | $ | 6.0 | | | $ | 4.9 | | 50% interest in ARO net income | $ | 0.7 | | | | | $ | 4.1 | |
| Amortization of basis differences | Amortization of basis differences | 2.5 | | | | (2.9) | | | (16.4) | | Amortization of basis differences | 3.6 | | | | | (2.2) | |
| Equity in earnings (losses) of ARO | $ | 4.8 | | | | $ | 3.1 | | | $ | (11.5) | | |
| Equity in earnings of ARO | | Equity in earnings of ARO | $ | 4.3 | | | | | $ | 1.9 | |
Related-Party Transactions
Revenues recognized by us related to the Lease Agreements Transition Services Agreement and Secondment Agreement are as follows (in millions):
| | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | | | |
| Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2020 | | | | |
| Lease revenue | $ | 10.3 | | | | $ | 5.1 | | | $ | 19.9 | | | | | |
| Secondment revenue | .4 | | | | .3 | | | .2 | | | | | |
Total revenue from ARO (1) | $ | 10.7 | | | | $ | 5.4 | | | $ | 20.1 | | | | | |
| | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | | | |
| Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 | | | | |
| Lease revenue | $ | 10.3 | | | | $ | 21.7 | | | $ | 41.4 | | | | | |
| Secondment and Transition Services revenue | .4 | | | | 1.1 | | | 22.0 | | | | | |
Total revenue from ARO (1) | $ | 10.7 | | | | $ | 22.8 | | | $ | 63.4 | | | | | |
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | | | Predecessor | | | | |
| Three Months Ended March 31, 2022 | | | | | Three Months Ended March 31, 2021 | | | | |
| Lease revenue | $ | 14.2 | | | | | | $ | 16.6 | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
(1) All of the revenuesRevenues presented above are included in our Other segment in our segment disclosures. See "Note 1512 - Segment Information" for additional information.
Amounts receivable from ARO related to the items above totaled $21.0$11.6 million and $21.6$12.1 million as of June 30, 2021 (Successor)March 31, 2022 and December 31, 2020 (Predecessor),2021, respectively, and are included in accountsAccounts receivable, net, on our Condensed Consolidated Balance Sheets.
We had $38.6$13.9 million and $30.9$37.1 million of Contract Liabilitiesliabilities and Accounts payable, respectively, related to ourthe Lease Agreements with ARO as of June 30, 2021 (Successor) andMarch 31, 2022. As of December 31, 2020 (Predecessor), respectively.2021, we had $10.8 million and $38.3 million of Contract liabilities and Accounts payable, respectively, related to the Lease Agreements. The per day bareboat charter amount in the Lease Agreements is subject to adjustment based on actual performance of the respective rig and as such Contract liabilities related to the Lease Agreements are subject to adjustment during the lease term. Upon completion of the lease term, such amount becomes a payable to or a receivable from ARO.
During 2017 and 2018, Rowanthe Company contributed cash to ARO in exchange for 10-yearten-year shareholder notes receivable atbased on a stated interestone-year LIBOR rate, of LIBOR plus two percent. As of June 30, 2021 (Successor) and December 31, 2020 (Predecessor), the carrying amountset as of the long-term notes receivable from ARO was $234.3 million and $442.7 million, respectively.end of the year prior to the year applicable, plus 2 percent. The notes receivable were adjusted to fair value as of the emergence date. TheEffective Date by recording a discount to the carryingprincipal amount will beof $442.7 million. The discount is being amortized using the effective interest method to interest income over the remaining terms of the notes. As of March 31, 2022 and December 31, 2021, the carrying amount of the long-term notes receivable from ARO was $256.8 million and $249.1 million, respectively. The Shareholders’ Agreementagreement entered into by us and Saudi Aramco to create ARO 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 toDuring the joint venture. Interest is recognized asthree months ended March 31, 2022 (Successor), interest income in our Condensed Consolidated Statementtotaled $10.5 million of Operations. Forwhich $7.7 million pertains to non-cash amortization of the Successor, duringdiscount on the twoshareholder notes. During the three months ended June 30,March 31, 2021 (Predecessor), interest income totaled $1.7$2.6 million. For the Predecessor, the one month and four months ended April 30, 2021, interest totaled $0.9 million and $3.5 million
respectively. Interest totaled $4.6 million and $9.2 million for the three and six months ended June 30, 2020, respectively. As of June 30, 2021 (Successor),March 31, 2022, our interest receivable from ARO was $5.2$2.9 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 (Predecessor).2021.
Maximum Exposure to Loss
The following table summarizes the total assets and liabilities as reflected in our 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 oncarrying amount of our shareholder notes receivable; and (3) other receivables and contract assets related to services provided tofrom ARO, partially offset by contract liabilities as well as payables for services received. Contract liabilities related to our Lease Agreements are subject to adjustment during the lease term. The per day bareboat charter amount in the Lease Agreements is subject to adjustment based on actual performance of the respective rig.ARO.
| | | Successor | | | Predecessor | |
| | June 30, 2021 | | | December 31, 2020 | | March 31, 2022 | | December 31, 2021 |
| Total assets | Total assets | $ | 340.7 | | | | $ | 585.2 | | Total assets | $ | 362.9 | | | $ | 348.1 | |
| Less: total liabilities | Less: total liabilities | 38.6 | | | | 30.9 | | Less: total liabilities | 51.0 | | | 49.1 | |
| Maximum exposure to loss | Maximum exposure to loss | $ | 302.1 | | | | $ | 554.3 | | Maximum exposure to loss | $ | 311.9 | | | $ | 299.0 | |
Note 64 -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 December 31, 2020 (Predecessor) | | | | | | | |
| Supplemental executive retirement plan assets | 22.6 | | | 0 | | | 0 | | | 22.6 | |
| | | | | | | |
| Total financial assets | $ | 22.6 | | | $ | 0 | | | $ | 0 | | | $ | 22.6 | |
Supplemental Executive Retirement Plan Assets
Our supplemental executive retirement plans (the "SERP") are non-qualified plans that provided 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 are 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 as of December 31, 2020. The fair value measurements of assets held in the SERP were based on quoted market prices. Pursuant to the plan of reorganization, the assets held in the rabbi trust maintained for the SERP were liquidated upon emergence from Chapter 11 Cases and used to satisfy the claims of creditors.
Other Financial Instruments
The carrying values and estimated fair values of our long-term debt instrumentsinstrument were as follows (in millions):
| | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | Predecessor |
| June 30,
2021 | | December 31,
2020 |
| Carrying Value | | Estimated Fair Value | | Carrying Value | | Estimated Fair Value |
| Secured first lien notes due 2028 | $ | 544.8 | | | $ | 570.1 | | | $ | 0 | | | $ | 0 | |
| 6.875% Senior notes due 2020 | 0 | | | 0 | | | 122.9 | | | 8.6 | |
| 4.70% Senior notes due 2021 | 0 | | | 0 | | | 100.7 | | | 4.5 | |
| 4.875% Senior notes due 2022 | 0 | | | 0 | | | 620.8 | | | 32.9 | |
3.00% Exchangeable senior notes due 2024(1) | 0 | | | 0 | | | 849.5 | | | 76.5 | |
| 4.50% Senior notes due 2024 | 0 | | | 0 | | | 303.4 | | | 13.7 | |
| 4.75% Senior notes due 2024 | 0 | | | 0 | | | 318.6 | | | 18.8 | |
| 8.00% Senior notes due 2024 | 0 | | | 0 | | | 292.3 | | | 12.9 | |
| 5.20% Senior notes due 2025 | 0 | | | 0 | | | 333.7 | | | 12.7 | |
| 7.375% Senior notes due 2025 | 0 | | | 0 | | | 360.8 | | | 20.9 | |
| 7.75% Senior notes due 2026 | 0 | | | 0 | | | 1,000.0 | | | 44.0 | |
| 7.20% Debentures due 2027 | 0 | | | 0 | | | 112.1 | | | 5.7 | |
| 7.875% Senior notes due 2040 | 0 | | | 0 | | | 300.0 | | | 21.0 | |
| 5.40% Senior notes due 2042 | 0 | | | 0 | | | 400.0 | | | 23.6 | |
| 5.75% Senior notes due 2044 | 0 | | | 0 | | | 1,000.5 | | | 38.0 | |
| 5.85% Senior notes due 2044 | 0 | | | 0 | | | 400.0 | | | 26.0 | |
Amounts borrowed under Revolving Credit Facility(2) | 0 | | | 0 | | | 581.0 | | | 581.0 | |
| Total debt | $ | 544.8 | | | $ | 570.1 | | | $ | 7,096.3 | | | $ | 940.8 | |
Less : Liabilities Subject to Compromise(3) | 0 | | | 0 | | | 7,096.3 | | | 940.8 | |
| Total long-term debt | $ | 544.8 | | | $ | 570.1 | | | $ | 0 | | | $ | 0 | |
| | | | | | | |
| | | | | | | |
(1) For the Predecessor, the 3% exchangeable senior notes due 2024 (the "2024 Convertible Notes") were 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 December 31, 2020 represented the aggregate principal amount of these notes as of the Petition Date and were classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of December 31, 2020. The Predecessor discontinued accruing interest on these notes as of the Petition Date. The equity component was $220.0 million and was classified as Additional Paid-in Capital as of December 31, 2020. On the Effective Date, in accordance with the plan of reorganization, all outstanding obligations under the 2024 Convertible Notes were cancelled and the equity component was written off to retained earnings.
(2) In addition to the amount borrowed above, the Predecessor had $27.0 million in undrawn letters of credit issued under the Revolving Credit Facilityas of December 31, 2020. On the emergence date, in accordance with the plan of reorganization, all undrawn letters of credit issued under the Revolving Credit Facility were collateralized pursuant to the terms of the RevolvingCredit Facility. As of June 30, 2021, we had $22.0 million of collateralized letters of credit issued to lenders of the predecessor Revolving Credit Facility.
(3) As discussed in “Note 2 - Chapter 11 Proceedings” and “Note 3 - Fresh Start Accounting,” since the commencement of the Chapter 11 Cases on August 19, 2020 and through April 30, 2021, the Company operated as a debtor-in-possession under the jurisdiction of the Bankruptcy Court and in accordance with the provisions of the Bankruptcy Code. Accordingly, all of our long-term debt obligations were presented as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of December 31, 2020. All unamortized debt discounts, premiums or issuance costs related to our long-term debt obligations were written off to reorganization items as of the Petition Date in 2020. | | | | | | | | | | | | | | | | | | | | | | | |
| | | |
| March 31,
2022 | | December 31,
2021 |
| Carrying Value | | Estimated Fair Value | | Carrying Value | | Estimated Fair Value |
| Senior secured first lien notes due 2028 | $ | 545.5 | | | $ | 569.1 | | | $ | 545.3 | | | $ | 575.7 | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
The estimated fair valuesvalue of the Successor'sSenior Secured First Lien Notes and the Predecessor's Senior Notes(the "First Lien Notes") werewas determined using quoted market prices, which are level 1 inputs. The
As of March 31, 2022, the estimated fair value of our notes receivable from ARO was $274.9 million and was estimated by using an income approach to value the forecasted cash flows attributed to the notenotes receivable using a discount rate based on comparable yield with a country-specific risk premiumpremium.
The estimated fair values of our cash and cash equivalents, restricted cash, accounts receivable and trade payables approximated their carrying values as of June 30, 2021March 31, 2022 and December 31, 2020.
As discussed above, the carrying amount at December 31, 2020 represents the Predecessor's outstanding borrowings as of the Petition Date and are classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of December 31, 2020. We discontinued accruing interest on our indebtedness as of the Petition Date.2021.
Note 75 -Property and Equipment
Property and equipment as of June 30, 2021 and December 31, 2020 consisted of the following (in millions):
| | | | | | | | | | | | | | | | | |
| | Successor | | | Predecessor |
| | June 30,
2021 | | | December 31, 2020 |
| Drilling rigs and equipment | | $ | 855.8 | | | | $ | 12,584.4 | |
| Work-in-progress | | 23.4 | | | | 446.1 | |
| Other | | 35.2 | | | | 178.8 | |
| | $ | 914.4 | | | | $ | 13,209.3 | |
Predecessor Impairments of Long-Lived Assets
During the four months ended April 30, 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 three and six months ended June 30, 2020 we recorded an aggregate pre-tax, non-cash impairment with respect to certain floaters, jackups and spare equipment of $832.3 million and $3.6 billion respectively, which were included in loss on impairment in our Condensed Consolidated Statement of Operations. | | | | | | | | | | | | | | |
| | | | |
| | March 31,
2022 | | December 31, 2021 |
| Drilling rigs and equipment | | $ | 938.7 | | | $ | 886.9 | |
| Work-in-progress | | 42.6 | | | 35.6 | |
| Other | | 37.5 | | | 34.5 | |
| | $ | 1,018.8 | | | $ | 957.0 | |
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 wereare determined not to be recoverable, we recordedrecord an impairment for the difference between their fair values and carrying values.
Predecessor
During the first quarter of 2021, as a result of challenging market conditions for certain of our floaters, we revised our near-term operating assumptions which 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 of 2021 for certain floaters totaling $756.5 million.million, inclusive of $5.6 million of gains reclassified from accumulated other comprehensive income into loss on impairment associated with related cash flow hedges. We measured the fair value of these assets to be $26.0 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.
During the second quarter of 2020, given the anticipated sustained market impacts arising from the decline in oil priceAssets held-for-sale and demand late in the first quarter, we revised our long-term operating assumptions which resulted in a triggering event for purposes of evaluating impairment and we performed a fleet-wide recoverability test. As a result, we recorded a pre-tax, non-cash impairment with respect to 2 floaters and spare equipment totaling $817.3 million. We measured the fair value of these assets to be $69.0 million at the time of impairment by applying an income approach or estimated scrap value. These valuations were based on unobservable inputs that require significant judgments for which there is limited information including, in the case of the income approach, assumptions regarding future day rates, utilization, operating costs and capital requirements.
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 respect 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-salesold
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 Indenture dated April 30, 2021 that governs our First Lien Notes Indenture, see “Note 11 – Debt" for additional details on restrictions,(the “Indenture”), 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 brokerbrokers to market certain rigs. See “Note 8 – Debt" for additional information on restrictions on the sales of assets.
On a quarterly basis, we assess whether any riglong-lived assets meets the criteria established for held-for-sale classification on our balance sheet. All rigsAssets 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
Assetsnecessary. No assets were considered as held-for-sale had an aggregate carrying value of $1.0 million and $2.3 million and is included in other assets, net, on our Condensed Consolidated Balance SheetSheets as of June 30, 2021 (Successor) andMarch 31, 2022, or December 31, 20202021.
VALARIS 67 was sold during the three months ended March 31, 2022 (Successor) resulting in a pre-tax gain of $2.0 million, which is included in Other, net on the Condensed Consolidated Statements of Operations for the three months ended March 31, 2022 (Successor).
During the three months ended March 31, 2021 (Predecessor), respectively.our Australia office building was sold, resulting in an immaterial pre-tax gain, which is included in Other, net on the Condensed Consolidated Statements of Operations for the three months ended March 31, 2021 (Predecessor).
Subsequent to March 31, 2022, we reached an agreement for the sale of VALARIS 113 and VALARIS 114, resulting in an expected pre-tax gain on sale to be recorded in the second quarter of 2022 of approximately $120 million.
Note 86 -Pension and Other Post-retirement Benefits
We have defined-benefit pension plans and a retiree medical planplans that providesprovide post-retirement health and life insurance benefits.
The components of net periodic pension and retiree medical cost were as follows (in millions):
| | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | | | |
| | Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2020 | | | | |
Service cost (1) | $ | 0 | | | | $ | 0 | | | $ | .7 | | | | | |
Interest cost (2) | 3.8 | | | | 1.6 | | | 6.4 | | | | | |
Expected return on plan assets(2) | (6.2) | | | | (3.0) | | | (9.5) | | | | | |
| | | | | | | | | | |
| Net periodic pension and retiree medical cost (income) | $ | (2.4) | | | | $ | (1.4) | | | $ | (2.4) | | | | | |
| | | Successor | | | Predecessor | | Successor | | | | Predecessor | |
| | | Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 | | Three Months Ended March 31, 2022 | | | | Three Months Ended March 31, 2021 | |
Service cost (1) | $ | 0 | | | | $ | 0 | | | $ | 1.3 | | |
| Interest cost (2) | Interest cost (2) | 3.8 | | | | 6.6 | | | 12.9 | | Interest cost (2) | 5.5 | | | | | 5.0 | | |
Expected return on plan assets(2) | Expected return on plan assets(2) | (6.2) | | | | (12.1) | | | (19.0) | | Expected return on plan assets(2) | (9.5) | | | | | (9.1) | | |
Amortization of net loss (2) | Amortization of net loss (2) | 0 | | | | .1 | | | 0 | | Amortization of net loss (2) | — | | | | | 0.1 | | |
| Net periodic pension and retiree medical cost (income) | $ | (2.4) | | | | $ | (5.4) | | | $ | (4.8) | | |
Net periodic pension and retiree medical income (1) | | Net periodic pension and retiree medical income (1) | $ | (4.0) | | | | | $ | (4.0) | | |
(1)Included in contract drilling and general and administrative expense in our Condensed Consolidated Statements of Operations.
(2)Included in other,Other, net, in our Condensed Consolidated Statements of Operations.
During the two months ended June 30, 2021 (Successor), we contributed $0.6 million to our pension and other post-retirement benefit plans. During the four months ended April 30, 2021 (Predecessor), we contributed $22.5 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, inIn 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 contributionscurrently expect to certaincontribute or directly pay approximately $4.2 million to our pension and other post-retirement benefits plans for the remainder of 2021. However, we expect to make contributions to certain other plans for the remainder of 2021 of approximately $1.3 million.2022. These amounts represent the minimum contributions we are required to make under relevant statutes. We do not expect to make contributions in excess of the minimum required amounts.
Note 9 -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 previously used derivatives to reduce our exposure to various market risks, primarily foreign currency exchange rate risk.
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 with us in September 2020. As a result, we do not have derivative assets or liabilities on our Condensed Consolidated Balance Sheets as of December 31, 2020 (Predecessor). During the four months ended April 30, 2021 (Predecessor) and two months ended June 30, 2021 (Successor), we did not enter into derivative contracts; therefore, we do not have derivative assets or liabilities on our Condensed Consolidated Balance Sheet as of June 30, 2021.
We previously 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 expense and capital expenditures denominated in various currencies.
Gains and losses, net of tax, on derivatives designated as cash flow hedges included in our Condensed Consolidated Statements of Operations and comprehensive loss were as follows (in millions):
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Gain Recognized in Other Comprehensive Loss ("OCI") on Derivatives (Effective Portion) | | Gain Reclassified from ("AOCI") into Income (Effective Portion)(1) |
| Successor | | Predecessor | | Successor | | Predecessor |
| Two Months Ended June 30, 2021 | | One Month Ended April 30, 2021 | Three Months Ended June 30, 2020 | | Two Months Ended June 30, 2021 | | One Month Ended April 30, 2021 | Three Months Ended June 30, 2020 |
| | | | | | | | | |
| | | | | | | | | |
Foreign currency forward contracts(2) | $ | 0 | | | $ | 0 | | $ | 4.8 | | | $ | 0 | | | $ | 0 | | $ | (10.9) | |
| | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Loss Recognized in Other Comprehensive Loss ("OCI") on Derivatives (Effective Portion) | | Gain Reclassified from ("AOCI") into Income (Effective Portion)(1) |
| Successor | | Predecessor | | Successor | | Predecessor |
| Two Months Ended June 30, 2021 | | Four Months Ended April 30, 2021 | Six Months Ended June 30, 2020 | | Two Months Ended June 30, 2021 | | Four Months Ended April 30, 2021 | Six Months Ended June 30, 2020 |
| | | | | | | | | |
| | | | | | | | | |
Foreign currency forward contracts(3) | $ | 0 | | | $ | 0 | | $ | (8.1) | | | $ | 0 | | | $ | (5.6) | | $ | (11.0) | |
| | | | | | | | | |
(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 June 30, 2020 (Predecessor), $1.6 million of losses were reclassified from AOCI into contract drilling expense and $12.5 million of gains were reclassified from AOCI into depreciation expense in our Condensed Consolidated Statement of Operations.
(3)During the four months ended April 30, 2021 (Predecessor), $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 six months ended June 30, 2020 (Predecessor), $2.5 million of losses were reclassified from AOCI into contract drilling expense and $13.5 million 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. Historically, we have occasionally entered into derivatives that hedge the fair value of recognized foreign currency denominated assets or liabilities but did not designate such derivatives as hedging instruments. In these situations, a natural hedging relationship generally existed whereby changes in the fair value of the derivatives offset changes in the fair value of the underlying hedged items. Net gains of $1.4 million and $1.3 million associated with our derivatives not designated as hedging instruments were included in other, net, in our Condensed Consolidated Statement of Operations for the three months and six months ended June 30, 2020 (Predecessor), respectively.
Note 107 -Earnings Per Share
Basic income (loss) per share is computed by dividing net income (loss) available to common shareholders by the weighted-average number of common shares outstanding during the period. Basic and diluted earnings per share ("EPS") for the Predecessor was calculated in accordance with the two-class method. Predecessor net loss attributable to Legacy Valaris used in our computations of basic and diluted EPS was 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 for the Successor includes the effect of all potentially dilutive warrants, restricted stock unit awards and performance stock unit awards and for the Predecessor includes the effect of all potentially dilutive stock options and Warrants and excludes non-vested shares. For the Successor, during the twothree months ended June 30, 2021,March 31, 2022, 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. ForAdditionally, for the Predecessor, during the one month and fourthree months ended April 30,March 31, 2021, and three and six months ended June 30, 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.
For the Successor, during the twothree months ended June 30,March 31, 2022, loss from continuing operations attributable to our shares was $38.6 million.
For the Predecessor, during the three months ended March 31, 2021, loss from continuing operations attributable to Legacy Valaris and Legacy Valaris shares was $6.2$910.0 million. No amounts were allocated to non-vested share awards in this period given that losses are not allocated to non-vested share awards.
For the Predecessor, during one month and four months ended April 30, 2021, loss from continuing operations attributable to Valaris shares was $3.6 billion and $4.5 billion respectively. No amounts were allocated to non-vested share awards in either period given that losses are not allocated to non-vested share awards. During three and six months ended June 30, 2020, loss from continuing operations attributable to Valaris shares were $1.1 billion and $4.1 billion respectively.
For the Successor, during the two months ended June 30, 2021, there were 29,000 anti-dilutive shares. For the Predecessor, during the one month and four months ended April 30, 2021, anti-dilutiveAnti-dilutive share awards totaling 1.0 million and 300,000 for the three months ended March 31, 2022 (Successor) and the three months ended March 31, 2021 (Predecessor), respectively, were excluded from the computation of diluted EPS respectively. Anti-dilutive share awards totaling 400,000 were excluded from the computation of diluted EPS for the three and six months ended June 30, 2020, respectively.EPS. Due to the net loss position, potentially dilutive share awards are excluded from the computation of diluted EPS.
On the Effective Date and pursuantWe have 5,470,972 warrants outstanding (the "Warrants") as of March 31, 2022 to the planpurchase common shares of reorganization, all of the Predecessor's ordinary shares were cancelled. In accordance with the plan of reorganization, all agreements, instruments and other documents evidencing, relating or otherwise connected with any of Legacy Valaris' equity interests outstanding prior to the Effective Date, including all equity-based awards, were cancelled.
On the Effective Date and pursuant to the plan of reorganization, the Company issued 5,645,161 Warrants, to the former holders of the Company's equity interests outstanding prior to the Effective Date. The WarrantsValaris Limited which are exercisable for one Common Share per Warrant at an initial exercise price of $131.88 per Warrant, in each case as may be adjusted from time to time pursuant to the applicable warrant agreement. The Warrants are exercisable for a period of seven years and will expire on April 29, 2028. The exercise of these Warrants into Common Shares would have a dilutive effect to the holdings of Valaris’sValaris Limited's existing shareholders. These warrants are anti-dilutive for the three months ended March 31, 2022.
Note 118 -Debt
First Lien Notes Indenture
On the Effective Date, in accordance with the plan of reorganization and Backstop Commitment Agreement, dated August 18, 2020 (as amended, the "BCA"), the Company consummated the rights offering of senior secured first lien notes (“the First Lien Notes”)Notes and associated shares in an aggregate principal amount of $550.0 million, In accordance with the BCA, certain holders of senior notes claims and certain holders of claims under the Revolving Credit Facility ("Backstop Parties") who provided backstop commitments received the backstop premium.million.
The First Lien Notes were issued pursuant to the Indenture, dated April 30, 2021 (the “First Lien Notes Indenture”), among the Company,Valaris Limited, certain direct and indirect subsidiaries of the CompanyValaris Limited as guarantors, and Wilmington Savings Fund Society, FSB, as collateral agent and trustee (in such capacities, the “Collateral Agent”).
The First Lien Notes are guaranteed, jointly and severally, on a senior basis, by certain of the direct and indirect subsidiaries of the Company under the First Lien Notes Indenture.Company. The First Lien Notes and such guarantees are secured by first-priority perfected liens on 100% of the equity interests of each Restricted Subsidiaryrestricted subsidiary directly owned by the Company or any guarantor and a first-priority perfected lien on substantially all assets of the Company and each guarantor of the First Lien Notes, in each case subject to certain exceptions and limitations. The following is a brief description of the material provisions of the First Lien Notes Indenture and the First Lien Notes.
The First Lien Notes are scheduled to mature on April 30, 2028. Interest on the First Lien Notes accrues, at Valaris’sour option, at a rate of: (i) 8.25% per annum, payable in cash; (ii) 10.25% per annum, with 50% of such interest to be payable in cash and 50% of such interest to be paid in kind; or (iii) 12% per annum, with the entirety of such interest to be paid in kind. The Company shall pay interestInterest is due semi-annually in arrears on May 1 and November 1 of each year commencing November 1, 2021. Interest on the First Lien Notes shall accrue from the most recent date to which interest has been paid or, if no interest has been paid, from April 30, 2021. Interestand shall be computed on the basis of a 360-day year of twelve 30-day months.
At any time prior to April 30, 2023, the Company may redeem up to 35% of the aggregate principal amount of the First Lien Notes at a redemption price of 104% up to the net cash proceeds received by the Company from equity offerings provided that at least 65% of the aggregate principal amount of the First Lien Notes remains outstanding and provided that the redemption occurs within 120 days after such equity offering of the Company. At any time prior to April 30, 2023, the Company may redeem the First Lien Notes at a redemption price of 104% plus a “make-whole” premium. On or after April 30, 2023, the Company may redeem all or part of the First Lien Notes at fixed redemption prices (expressed as percentages of the principal amount), plus accrued and unpaid interest, if any, to, but excluding, the redemption date. The Company may also redeem the First Lien Notes, in whole or in part, at any time and from time to time on or after April 30, 2026 at a redemption price equal to 100% of the principal amount plus accrued and unpaid interest, if any, to, but excluding, the applicable redemption date. Notwithstanding the foregoing, if a Change of Control (as defined in the First Lien Notes Indenture, with certain exclusions as provided therein) occurs, the Company will be required to make an offer to repurchase all or any part of each note holder’s notes at a purchase price equal to 101% of the aggregate principal amount of First Lien Notes repurchased, plus accrued and unpaid interest to, but excluding, the applicable date.
The First Lien Notes Indenture contains covenants that limit, among other things, the Company’s ability and the ability of the guarantors and other restricted subsidiaries, to: (i) incur, assume or guarantee additional indebtedness; (ii) pay dividends or distributions on Equity Interests (as defined in the First Lien Notes Indenture)equity interests or redeem or repurchase Equity Interests;equity interests; (iii) make investments; (iv) repay or redeem junior debt; (v) transfer or sell assets; (vi) enter into sale and lease back transactions; (vii) create, incur or assume liens; and (viii) enter into transactions with certain affiliates. These covenants are subject to a number of important limitations and exceptions.
The First Lien Notes Indenture also provides for certain customary events of default, including, among other things, nonpayment of principal or interest, breach of covenants, failure to pay final judgments in excess of a specified threshold, failure of a guarantee to remain in effect, failure of a collateral document to create an effective security interest in collateral, with a fair market value in excess of a specified threshold, bankruptcy and insolvency events, cross payment default and cross acceleration, which could permit the principal, premium, if any, interest and other monetary obligations on all the then outstanding First Lien Notes to be declared due and payable immediately.
The Company incurred $5.2 million in issuance costs in association with the First Lien Notes that will beare being amortized into interest expense over the expected life of the notes using the effective interest method.
Predecessor Debtor in Possession Financing
On September 25, 2020, following approval by the Bankruptcy Court, the Debtors entered into the Debtor-in-Possession ("DIP") 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 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. As of the Effective Date, there were 0 borrowings outstanding against our DIP facility and there were no DIP claims that were not due and payable on, or that otherwise survived, the Effective Date. The DIP Credit Agreement terminated on the Effective Date.
Predecessor Senior Notes and Revolving Credit Facility
On the Effective Date, in accordance with the plan of reorganization, all outstanding obligations under the Predecessor's senior notes, including the 2024 Convertible Notes, and the Revolving Credit Facility were cancelled and the holders thereunder received their pro rata share of certain Common Shares issued on the Effective Date. See “Note 12 - Shareholders' Equity" for additional information regarding the issuance of the Common Shares.
Note 129 -Shareholders' Equity
Activity in our various shareholders' equity accounts for the twothree months ended June 30, 2021March 31, 2022 (Successor), one month and fourthe three months ended April 30,March 31, 2021 (Predecessor), and three and six months ended June 30, 2020 (Predecessor) were as follows (in millions, except per share amounts):
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| Shares | | Par Value | | Additional
Paid-in
Capital | | Warrants | | Retained
Earnings (Deficit) | | AOCI | | Treasury
Shares | | Non-controlling
Interest |
| BALANCE, December 31, 2020 (Predecessor) | 206.1 | | | $ | 82.6 | | | $ | 8,639.9 | | | $ | 0 | | | $ | (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 | | | — | |
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| Net changes in pension and other postretirement benefits | — | | | — | | | — | | | — | | | — | | | .1 | | | — | | | — | |
| Share-based compensation cost | — | | | — | | | 3.8 | | | — | | | — | | | — | | | — | | | — | |
| Net other comprehensive loss | — | | | — | | | — | | | — | | | — | | | (5.4) | | | — | | | — | |
| BALANCE, March 31, 2021 (Predecessor) | 206.1 | | | $ | 82.6 | | | $ | 8,643.5 | | | $ | 0 | | | $ | (5,093.8) | | | $ | (93.2) | | | $ | (76.0) | | | $ | (1.9) | |
| Net loss | — | | | — | | | — | | | — | | | (3,557.0) | | | — | | | — | | | .8 | |
| Shares issued under share-based compensation plans, net | 0 | | | 0 | | | (.5) | | | — | | | — | | | — | | | .5 | | | — | |
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| Share-based compensation cost | — | | | — | | | 1.0 | | | — | | | — | | | — | | | — | | | — | |
| Net other comprehensive loss | — | | | — | | | — | | | — | | | — | | | (.2) | | | — | | | — | |
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| Cancellation of Predecessor equity | (206.1) | | | (82.6) | | | (8,644.0) | | | — | | | 8,650.8 | | | 93.4 | | | 75.5 | | | — | |
| Issuance of Successor Common Shares and Warrants | 75.0 | | | 0.8 | | | 1,078.7 | | | 16.4 | | | — | | | — | | | — | | | — | |
| BALANCE, April 30, 2021 (Predecessor) | 75.0 | | | $ | 0.8 | | | $ | 1,078.7 | | | $ | 16.4 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | (1.1) | |
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| BALANCE, May 1, 2021 (Successor) | 75.0 | | | $ | 0.8 | | | $ | 1,078.7 | | | $ | 16.4 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | (1.1) | |
| Net income | — | | | — | | | — | | | — | | | (6.2) | | | — | | | — | | | $ | 2.1 | |
| Net other comprehensive income | — | | | — | | | — | | | — | | | — | | | (0.2) | | | — | | | $ | — | |
| BALANCE, June 30, 2021 (Successor) | 75.0 | | | $ | 0.8 | | | $ | 1,078.7 | | | $ | 16.4 | | | $ | (6.2) | | | $ | (0.2) | | | $ | 0 | | | $ | 1.0 | |
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| Shares | | Par Value | | Additional
Paid-in
Capital | | Retained
Earnings (Deficit) | | AOCI | | Treasury
Shares | | Non-controlling
Interest |
| BALANCE, December 31, 2019 (Predecessor) | 205.9 | | | $ | 82.5 | | | $ | 8,627.8 | | | $ | 671.7 | | | $ | 6.2 | | | $ | (77.3) | | | $ | (1.3) | |
| Net loss | — | | | — | | | — | | | (3,006.3) | | | — | | | — | | | (1.4) | |
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| 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, 2020 (Predecessor) | 205.9 | | | $ | 82.5 | | | $ | 8,634.9 | | | $ | (2,334.6) | | | $ | (7.2) | | | $ | (77.3) | | | $ | (2.7) | |
| Net loss | — | | | — | | | — | | | (1,107.4) | | | — | | | — | | | (1.4) | |
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| Shares issued under share-based compensation plans, net | .2 | | | .1 | | | (.7) | | | — | | | — | | | .6 | | | — | |
| Repurchase of shares | — | | | — | | | — | | | — | | | — | | | (.1) | | | — | |
| Share-based compensation cost | — | | | — | | | 5.7 | | | — | | | — | | | — | | | — | |
| Net other comprehensive loss | — | | | — | | | — | | | — | | | (6.1) | | | — | | | — | |
| Distributions to noncontrolling interests | | | | | | | | | | | | | $ | (0.9) | |
BALANCE, June 30, 2020
(Predecessor) | 206.1 | | | $ | 82.6 | | | $ | 8,639.9 | | | $ | (3,442.0) | | | $ | (13.3) | | | $ | (76.8) | | | $ | (5.0) | |
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| Shares | | Par Value | | Additional
Paid-in
Capital | | Warrants | | Retained
Earnings (Deficit) | | AOCI | | | | Non-controlling
Interest |
| BALANCE, December 31, 2021 (Successor) | 75.0 | | | $ | 0.8 | | | $ | 1,083.0 | | | $ | 16.4 | | | $ | (33.0) | | | $ | (9.1) | | | | | $ | 2.7 | |
| Net loss | — | | | — | | | — | | | — | | | (38.6) | | | — | | | | | (1.2) | |
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| Share-based compensation cost | — | | | — | | | 3.4 | | | — | | | — | | | — | | | | | — | |
| Net other comprehensive loss | — | | | — | | | — | | | — | | | — | | | (0.3) | | | | | — | |
| BALANCE, March 31, 2022 (Successor) | 75.0 | | | $ | 0.8 | | | $ | 1,086.4 | | | $ | 16.4 | | | $ | (71.6) | | | $ | (9.4) | | | | | $ | 1.5 | |
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Valaris Share Capital | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Shares | | Par Value | | Additional
Paid-in
Capital | | | | Retained
Earnings (Deficit) | | AOCI | | Treasury
Shares | | Non-controlling
Interest |
| BALANCE, December 31, 2020 (Predecessor) | 206.1 | | | $ | 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 | — | | | — | | | (0.2) | | | | | — | | | — | | | 0.2 | | | — | |
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| Net changes in pension and other postretirement benefits | — | | | — | | | — | | | | | — | | | 0.1 | | | — | | | — | |
| Share-based compensation cost | — | | | — | | | 3.8 | | | | | — | | | — | | | — | | | — | |
| Net other comprehensive loss | — | | | — | | | — | | | | | — | | | (5.4) | | | — | | | — | |
| BALANCE, March 31, 2021 (Predecessor) | 206.1 | | | $ | 82.6 | | | $ | 8,643.5 | | | | | $ | (5,093.8) | | | $ | (93.2) | | | $ | (76.0) | | | $ | (1.9) | |
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As of the Effective Date, the authorized share capital of Valaris is $8.5 million divided into 700 million Common Shares of a par value of $0.01 each and 150 million preference shares of a par value of $0.01.
Issuance of Common Shares
On the Effective Date, pursuant to the plan of reorganization, we issued 75 million Common Shares.
Cancellation of Predecessor Equity and Issuance of Warrants
On the Effective Date and pursuant to the plan of reorganization, the Legacy Valaris Class A ordinary shares were cancelled and the Company issued 5,645,161 Warrants to the former holders of the Company's equity interests outstanding prior to the Effective Date. The Warrants are exercisable for one Common Share per Warrant at initial exercise price of $131.88 per Warrant, in each case as may be adjusted from time to time pursuant to the applicable warrant agreement. The Warrants are exercisable for a period of seven years and will expire on April 29, 2028. The exercise of these Warrants into Common Shares would have a dilutive effect to the holdings of Valaris’s existing shareholders.
Management Incentive Plan
In accordance with the plan of reorganization, Valaris adopted the Valaris Limited 2021 Management Incentive Plan (the “MIP”) as of the Effective Date and authorized and reserved 8,960,573 Common Shares for issuance pursuant to equity incentive awards to be granted under the MIP, which may be in the form of incentive stock options, nonstatutory stock options, restricted stock, restricted stock units, stock appreciation rights, dividend equivalents and cash awards or any combination thereof.
Note 1310 -Income Taxes
Valaris Limited the Successor Company and our parent company, is domiciled and resident in Bermuda. 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-Bermuda subsidiaries is not subject to Bermuda taxation as there is not an income tax regime in Bermuda.
Legacy Valaris plc, the Predecessor Company and our former parent company was domiciled and resident in the U.K. The income of our non-U.K. subsidiaries was generally not subject to U.K. taxation.
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 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.
Our drilling rigs frequently move from one taxing jurisdiction to another to perform contract drilling services. In some instances, the movement of drilling rigs among taxing jurisdictions will involve the transfer of ownership of the drilling rigs among our subsidiaries. As a result of frequent changes in the taxing jurisdictions in which our drilling rigs are operated and/or owned, changes in profitability levels and changes in tax laws, our annual effective income tax rate may vary substantially from one reporting period to another.
Historically, we 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 the estimated annual effective tax rate, the historical method would not provide a reliable estimate of income taxes for the twothree months ended June 30, 2021March 31, 2022 (Successor), one month and fourthree months ended April 30,March 31, 2021 (Predecessor), and three and six months ended June 30, 2020 (Predecessor). We used a discrete effective tax rate method to calculate income taxes for the twothree months ended June 30,March 31, 2022 (Successor) and March 31, 2021 (Successor), one month and four months ended April 30, 2021 (Predecessor), and three and six months ended June 30, 2020 (Predecessor). 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 expensebenefit for the twothree months ended June 30, 2021(Successor)March 31, 2022 (Successor) was $5.6$14.5 million and was primarily attributable to changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and resolution of other prior period tax matters. Discrete income tax benefit for the one-month ended April 30, 2021 (Predecessor) was $18.1 million and was primarily attributable to fresh start accounting adjustments.years. Discrete income tax expense for the fourthree months ended April 30,March 31, 2021 (Predecessor) was $2.2$20.3 million and was primarily attributable to changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and resolution of other prior period tax matters offset by discrete tax benefit related to fresh start accounting adjustments. Excluding the aforementioned discrete tax items, income tax expense for the two months ended June 30, 2021 (Successor), one month and four months ended April 30, 2021 (Predecessor) was $9.5 million, $2.6 million and $14.0 million, respectively.
Discrete income tax benefit for the three months ended June 30, 2020 (Predecessor) was $47.3 million and was primarily attributable to rig impairments and other resolutions of prior year tax matters. Discrete income tax benefit for the six months ended June 30, 2020 (Predecessor) was $211.7 million and was primarily attributable to a restructuring transaction, rig impairments, implementation of the U.S. Cares Act, changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and resolution of other prior period tax
matters.years. Excluding the aforementioned discrete tax items, income tax expense for the three and six months ended June 30, 2020March 31, 2022 (Successor) and the three months ended March 31, 2021 (Predecessor) was $31.5$13.8 million and $43.9$11.4 million, respectively.
Unrecognized Tax Benefits
During 2019, the Luxembourg tax authorities issued aggregate tax assessments totaling approximately €142.0 million (approximately $168.4 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 a liability for uncertain tax positions of €93.0 million (approximately $110.3 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 $168.4 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 $93.7 million converted using the current period-end exchange rates) and €2.0 million (approximately $2.4 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 March 31, 2020 and is included in changes in operating assets and liabilities on the Condensed Consolidated Statement of Cash Flows for the six months ended June 30, 2020.
Note 1411 -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 event and have contacted the customer, us and other parties involved in drilling the well for additional information. We are cooperatingcooperated with the Indonesian authorities. We cannot predict the scope or ultimate outcome of this investigation. If the Indonesian authorities determine that we violated local laws in connection with this matter, we could be subject to penalties including environmental or other liabilities, which may have a material adverse impact on us.
ARO Newbuild Funding Obligations
Valaris and Saudi AramcoIn connection with our 50/50 unconsolidated joint venture, we have agreeda potential obligation to take all steps necessaryfund ARO for newbuild jackup rigs. ARO has plans to ensure that ARO purchasespurchase 20 newbuild jackup rigs ratably over an approximate 10-year period. In January 2020, ARO ordered the first 2 newbuild jackups 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. ARO paid a 25% down payment from cash on hand for each of the 2 newbuilds ordered in January 2020.2020 and is actively exploring financing options for remaining payments due upon delivery. In the event ARO has insufficient cash from operations or is unable to obtain third-party financing, each partner may periodically be required to make additional capital contributions to ARO, up to a maximum aggregate contribution of $1.25 billion from each partner to fund the newbuild program. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, as delivered, on a proportionate basis. The partners agreed that Saudi Aramco,
Letters of Credit
In the ordinary course of business with customers and others, we have entered into letters of credit to guarantee our performance as a customer, will provideit relates to our drilling contracts, to AROcontract bidding, customs duties, tax appeals and other obligations in connectionvarious jurisdictions. Letters of credit outstanding as of March 31, 2022 (Successor) totaled $33.6 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 acquisitionunderlying performance requirement. As of March 31, 2022 (Successor), we had collateral deposits in 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 minimumamount of another eight years of term, re-priced in three-year intervals based on a market pricing mechanism.$27.1 million with respect to these agreements.
Other Matters
In addition to the foregoing, we are named defendants or parties in certain other lawsuits, claims or proceedings incidental to our business and are involved from time to time as parties to governmental investigations or proceedings, including matters related to taxation, arising in the ordinary course of business. Although the outcome of such lawsuits or other proceedings cannot be predicted with certainty and the amount of any liability that could arise with respect to such lawsuits or other proceedings cannot be predicted accurately, we do not expect these matters to have a material adverse effect on our financial position, operating results and cash flows.
In the ordinary course of business with customers and others, we have entered into letters of credit to guarantee our performance as it relates to our drilling contracts, contract bidding, customs duties, tax appeals and other obligations in various jurisdictions. Letters of credit outstanding as of June 30, 2021 (Successor) totaled $114.4 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 June 30, 2021 (Successor), we had collateral deposits in the amount of $37.4 million with respect to these agreements.
Note 1512 -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.Agreements. Floaters, Jackups and ARO are also reportable segments.
Upon emergence, we ceased allocation of our onshore support costs included within contractContract drilling expenses to our operating segments for purposes of measuring segment operating income (loss) and as such, those costs are included in “Reconciling Items”. We have adjusted the historical periodsperiod to conform with current period presentation. Further, generalGeneral and administrative expense and depreciationDepreciation 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 propertyProperty and equipment.equipment, net.
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 53 - Equity Method Investment in ARO" for additional information on ARO and related arrangements.
Two Months Ended June 30,Segment information for the three months ended March 31, 2022 (Successor) and March 31, 2021 (Successor)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total | |
| Revenues | $ | 49.7 | | | $ | 128.5 | | | $ | 84.0 | | | $ | 24.6 | | | $ | (84.0) | | | $ | 202.8 | | |
| Operating expenses | | | | | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 45.2 | | | 95.5 | | | 62.9 | | | 9.2 | | | (44.1) | | | 168.7 | | |
| | | | | | | | | | | | |
| Depreciation | 7.9 | | | 7.8 | | | 9.7 | | | .8 | | | (9.6) | | | 16.6 | | |
| General and administrative | 0 | | | 0 | | | 3.1 | | | 0 | | | 9.6 | | | 12.7 | | |
| Equity in earnings of ARO | 0 | | | 0 | | | 0 | | | 0 | | | 4.8 | | | 4.8 | | |
| Operating income (loss) | $ | (3.4) | | | $ | 25.2 | | | $ | 8.3 | | | $ | 14.6 | | | $ | (35.1) | | | $ | 9.6 | | |
| Property and equipment, net | $ | 413.8 | | | $ | 396.2 | | | $ | 730.0 | | | $ | 49.8 | | | $ | (692.0) | | | $ | 897.8 | | |
One Month Ended April 30, 2021 (Predecessor)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | $ | 18.4 | | | $ | 59.8 | | | $ | 40.8 | | | $ | 12.1 | | | $ | (40.8) | | | $ | 90.3 | |
| Operating expenses | | | | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 21.7 | | | 48.8 | | | 29.8 | | | 4.7 | | | (19.4) | | | 85.6 | |
| | | | | | | | | | | |
| Depreciation | 15.9 | | | 17.3 | | | 4.9 | | | 3.5 | | | (4.1) | | | 37.5 | |
| General and administrative | 0 | | | 0 | | | 1.2 | | | 0 | | | 5.2 | | | 6.4 | |
| Equity in earnings of ARO | 0 | | | 0 | | | 0 | | | 0 | | | 1.2 | | | 1.2 | |
| Operating income (loss) | $ | (19.2) | | | $ | (6.3) | | | $ | 4.9 | | | $ | 3.9 | | | $ | (21.3) | | | $ | (38.0) | |
| Property and equipment, net | $ | 419.3 | | | $ | 401.4 | | | $ | 730.7 | | | $ | 50.5 | | | $ | (692.8) | | | $ | 909.1 | |
Four Months Ended April 30, 2021 (Predecessor)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | $ | 115.7 | | | $ | 232.4 | | | $ | 163.5 | | | $ | 49.3 | | | $ | (163.5) | | | $ | 397.4 | |
| Operating expenses | | | | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 106.0 | | | 169.3 | | | 116.1 | | | 19.8 | | | (73.4) | | | 337.8 | |
| Loss on impairment | 756.5 | | | 0 | | | 0 | | | 0 | | | 0 | | | 756.5 | |
| Depreciation | 72.1 | | | 69.7 | | | 21.0 | | | 14.8 | | | (18.0) | | | 159.6 | |
| General and administrative | 0 | | | 0 | | | 4.2 | | | 0 | | | 26.5 | | | 30.7 | |
| Equity in earnings of ARO | 0 | | | 0 | | | 0 | | | 0 | | | 3.1 | | | 3.1 | |
| Operating income (loss) | $ | (818.9) | | | $ | (6.6) | | | $ | 22.2 | | | $ | 14.7 | | | $ | (95.5) | | | $ | (884.1) | |
| Property and equipment, net | $ | 419.3 | | | $ | 401.4 | | | $ | 730.7 | | | $ | 50.5 | | | $ | (692.8) | | | $ | 909.1 | |
Three Months Ended June 30, 2020 (Predecessor)March 31, 2022 (Successor)
| | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total | |
| Revenues | Revenues | $ | 163.6 | | | $ | 186.3 | | | $ | 146.0 | | | $ | 38.9 | | | $ | (146.0) | | | $ | 388.8 | | Revenues | $ | 99.7 | | | $ | 180.7 | | | $ | 111.3 | | | $ | 38.0 | | | $ | (111.3) | | | $ | 318.4 | | |
| Operating expenses | Operating expenses | | Operating expenses | | |
| Contract drilling (exclusive of depreciation) | Contract drilling (exclusive of depreciation) | 150.5 | | | 163.5 | | | 112.5 | | | 15.3 | | | (71.1) | | | 370.7 | | Contract drilling (exclusive of depreciation) | 147.6 | | | 139.2 | | | 84.2 | | | 15.5 | | | (55.2) | | | 331.3 | | |
| Loss on impairment | 831.9 | | | .4 | | | 0 | | | 5.7 | | | 0 | | | 838.0 | | |
| | Depreciation | Depreciation | 62.0 | | | 52.8 | | | 13.3 | | | 11.2 | | | (7.8) | | | 131.5 | | Depreciation | 12.2 | | | 9.1 | | | 16.5 | | | 0.9 | | | (16.2) | | | 22.5 | | |
| General and administrative | General and administrative | 0 | | | 0 | | | 7.1 | | | 0 | | | 55.5 | | | 62.6 | | General and administrative | — | | | — | | | 5.2 | | | — | | | 13.6 | | | 18.8 | | |
| Equity in losses of ARO | 0 | | | 0 | | | 0 | | | 0 | | | (5.2) | | | (5.2) | | |
| Equity in earnings of ARO | | Equity in earnings of ARO | — | | | — | | | — | | | — | | | 4.3 | | | 4.3 | | |
| Operating income (loss) | Operating income (loss) | $ | (880.8) | | | $ | (30.4) | | | $ | 13.1 | | | $ | 6.7 | | | $ | (127.8) | | | $ | (1,019.2) | | Operating income (loss) | $ | (60.1) | | | $ | 32.4 | | | $ | 5.4 | | | $ | 21.6 | | | $ | (49.2) | | | $ | (49.9) | | |
| Property and equipment, net | Property and equipment, net | $ | 6,536.9 | | | $ | 4,000.6 | | | $ | 739.7 | | | $ | 600.4 | | | $ | (685.0) | | | $ | 11,192.6 | | Property and equipment, net | $ | 457.6 | | | $ | 387.1 | | | $ | 730.9 | | | $ | 51.7 | | | $ | (697.1) | | | $ | 930.2 | | |
SixThree Months Ended June 30, 2020March 31, 2021 (Predecessor)
| | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | Revenues | $ | 343.2 | | | $ | 399.1 | | | $ | 286.3 | | | $ | 103.1 | | | $ | (286.3) | | | $ | 845.4 | | Revenues | $ | 97.3 | | | $ | 172.6 | | | $ | 122.7 | | | $ | 37.2 | | | $ | (122.7) | | | $ | 307.1 | |
| Operating expenses | Operating expenses | | Operating expenses | |
| Contract drilling (exclusive of depreciation) | Contract drilling (exclusive of depreciation) | 339.3 | | | 370.1 | | | 220.8 | | | 49.4 | | | (132.9) | | | 846.7 | | Contract drilling (exclusive of depreciation) | 85.1 | | | 121.3 | | | 86.3 | | | 15.3 | | | (54.4) | | | 253.6 | |
| Loss on impairment | Loss on impairment | 3,386.2 | | | 254.3 | | | 0 | | | 5.7 | | | 0 | | | 3,646.2 | | Loss on impairment | 756.5 | | | — | | | — | | | — | | | — | | | 756.5 | |
| Depreciation | Depreciation | 151.4 | | | 111.3 | | | 26.3 | | | 22.3 | | | (15.3) | | | 296.0 | | Depreciation | 56.2 | | | 52.4 | | | 16.1 | | | 11.3 | | | (13.9) | | | 122.1 | |
| General and administrative | General and administrative | 0 | | | 0 | | | 15.4 | | | 0 | | | 100.6 | | | 116.0 | | General and administrative | — | | | — | | | 3.0 | | | — | | | 21.3 | | | 24.3 | |
| Equity in losses of ARO | 0 | | | 0 | | | 0 | | | 0 | | | (11.5) | | | (11.5) | | |
| | Equity in earnings of ARO | | Equity in earnings of ARO | — | | | — | | | — | | | — | | | 1.9 | | | 1.9 | |
| Operating income (loss) | Operating income (loss) | $ | (3,533.7) | | | $ | (336.6) | | | $ | 23.8 | | | $ | 25.7 | | | $ | (250.2) | | | $ | (4,071.0) | | Operating income (loss) | $ | (800.5) | | | $ | (1.1) | | | $ | 17.3 | | | $ | 10.6 | | | $ | (73.8) | | | $ | (847.5) | |
| Property and equipment, net | Property and equipment, net | $ | 6,536.9 | | | $ | 4,000.6 | | | $ | 739.7 | | | $ | 600.4 | | | $ | (685.0) | | | $ | 11,192.6 | | Property and equipment, net | $ | 5,685.4 | | | $ | 3,778.9 | | | $ | 729.2 | | | $ | 566.3 | | | $ | (675.9) | | | $ | 10,083.9 | |
Information about Geographic Areas
As of June 30, 2021,March 31, 2022, the geographic distribution of our and ARO's drilling rigs was as follows:
| | | Floaters | | Jackups | | Other | | Total Valaris | | ARO | | | Floaters | | Jackups | | Other | | Total Valaris | | ARO | |
| North & South America | North & South America | 5 | | 6 | | 0 | | 11 | | 0 | | North & South America | 6 | | 6 | | — | | 12 | | — | |
| Europe & the Mediterranean | Europe & the Mediterranean | 7 | | 14 | | 0 | | 21 | | 0 | | Europe & the Mediterranean | 6 | | 12 | | — | | 18 | | — | |
| Middle East & Africa | Middle East & Africa | 2 | | 8 | | 9 | | 19 | | 7 | | Middle East & Africa | 2 | | 7 | | 8 | | 17 | | 7 | |
| Asia & Pacific Rim | Asia & Pacific Rim | 2 | | 6 | | 0 | | 8 | | 0 | | Asia & Pacific Rim | 2 | | 6 | | — | | 8 | | — | |
| | Held-for-sale | 0 | | 1 | | 0 | | 1 | | 0 | | |
| | Total | Total | 16 | | 35 | | 9 | | 60 | | 7 | | Total | 16 | | 31 | | 8 | | 55 | | 7 | |
We provide management services in the U.S. Gulf of Mexico on 2 rigs owned by third-partiesa third party not included in the table above.
We are a party to contracts whereby we have the option to take delivery of 2 recently constructed drillships 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 1613 -Supplemental Financial Information
Condensed Consolidated Balance Sheet Information
Accounts receivable, net, consisted of the following (in millions):
| | | Successor | | | Predecessor | |
| | June 30,
2021 | | | December 31,
2020 | | March 31,
2022 | | December 31,
2021 |
| Trade | Trade | $ | 280.3 | | | | $ | 260.1 | | Trade | $ | 288.2 | | | $ | 296.8 | |
| Income tax receivable | Income tax receivable | 162.1 | | | | 190.6 | | Income tax receivable | 150.9 | | | 151.1 | |
| Other | Other | 10.0 | | | | 14.7 | | Other | 16.5 | | | 12.7 | |
| | | 452.4 | | | | 465.4 | | | 455.6 | | | 460.6 | |
| Allowance for doubtful accounts | Allowance for doubtful accounts | (16.3) | | | | (16.2) | | Allowance for doubtful accounts | (16.3) | | | (16.4) | |
| | | $ | 436.1 | | | | $ | 449.2 | | | $ | 439.3 | | | $ | 444.2 | |
Other current assets consisted of the following (in millions):
| | | Successor | | | Predecessor | |
| | June 30,
2021 | | | December 31,
2020 | | March 31,
2022 | | December 31,
2021 |
| Prepaid taxes | Prepaid taxes | $ | 44.4 | | | | $ | 32.9 | | Prepaid taxes | $ | 42.8 | | | $ | 44.4 | |
| Deferred costs | | Deferred costs | 31.8 | | | 26.9 | |
| Prepaid expenses | Prepaid expenses | 29.1 | | | | 43.4 | | Prepaid expenses | 21.4 | | | 23.1 | |
| Deferred costs | 20.2 | | | | 17.4 | | |
| Materials and supplies | 0 | | | | 279.4 | | |
| | Other | Other | 26.0 | | | | 13.4 | | Other | 29.7 | | | 23.4 | |
| | | $ | 119.7 | | | | $ | 386.5 | | | $ | 125.7 | | | $ | 117.8 | |
Other assets consisted of the following (in millions):
| | | Successor | | | Predecessor | |
| | June 30,
2021 | | | December 31,
2020 | | March 31,
2022 | | December 31,
2021 |
| Tax receivables | Tax receivables | $ | 65.8 | | | | $ | 66.8 | | Tax receivables | $ | 65.6 | | | $ | 64.8 | |
| Deferred tax assets | Deferred tax assets | 42.7 | | | | 21.9 | | Deferred tax assets | 60.8 | | | 59.7 | |
| Right-of-use assets | Right-of-use assets | 32.4 | | | | 35.8 | | Right-of-use assets | 22.1 | | | 20.5 | |
| Supplemental executive retirement plan assets | 0 | | | | 22.6 | | |
| | | Other | Other | 25.6 | | | | 29.1 | | Other | 38.1 | | | 31.0 | |
| | $ | 166.5 | | | | $ | 176.2 | | | $ | 186.6 | | | $ | 176.0 | |
Accrued liabilities and other consisted of the following (in millions):
| | | Successor | | | Predecessor | |
| | June 30,
2021 | | | December 31,
2020 | | March 31,
2022 | | December 31,
2021 |
| Personnel costs | Personnel costs | $ | 75.2 | | | | $ | 95.6 | | Personnel costs | $ | 58.2 | | | $ | 64.6 | |
| Deferred revenue | | Deferred revenue | 56.3 | | | 45.8 | |
| Income and other taxes payable | Income and other taxes payable | 51.5 | | | | 50.8 | | Income and other taxes payable | 48.6 | | | 45.7 | |
| | Deferred revenue | 35.2 | | | | 57.6 | | |
| Accrued interest | | Accrued interest | 18.9 | | | 7.6 | |
| Lease liabilities | Lease liabilities | 15.1 | | | | 15.7 | | Lease liabilities | 9.7 | | | 10.0 | |
| | Other | Other | 35.7 | | | | 30.7 | | Other | 20.4 | | | 22.5 | |
| | | $ | 212.7 | | | | $ | 250.4 | | | $ | 212.1 | | | $ | 196.2 | |
Other liabilities consisted of the following (in millions):
| | | Successor | | | Predecessor | |
| | June 30,
2021 | | | December 31,
2020 | | March 31,
2022 | | December 31,
2021 |
| Unrecognized tax benefits (inclusive of interest and penalties) | Unrecognized tax benefits (inclusive of interest and penalties) | $ | 298.8 | | | | $ | 286.1 | | Unrecognized tax benefits (inclusive of interest and penalties) | $ | 285.2 | | | $ | 320.2 | |
| Pension and other post-retirement benefits | Pension and other post-retirement benefits | 182.8 | | | | 296.6 | | Pension and other post-retirement benefits | 199.2 | | | 204.0 | |
| | Intangible liabilities | 0 | | | | 50.4 | | |
| Customer payable | — | | | | 35.5 | | |
| | Other | Other | 88.2 | | | | 93.8 | | Other | 60.4 | | | 56.9 | |
| | | $ | 569.8 | | | | $ | 762.4 | | | $ | 544.8 | | | $ | 581.1 | |
Accumulated other comprehensive income (loss) consisted of the following (in millions):
| | | Successor | | | Predecessor | |
| | June 30,
2021 | | | December 31,
2020 | | March 31,
2022 | | December 31,
2021 |
| Pension and other post-retirement benefits | | Pension and other post-retirement benefits | $ | (9.1) | | | $ | (9.1) | |
| Currency translation adjustment | Currency translation adjustment | $ | (.2) | | | | $ | 6.5 | | Currency translation adjustment | (0.3) | | | — | |
| Derivative instruments | 0 | | | | 5.6 | | |
| Pension and other post-retirement benefits | 0 | | | | (98.2) | | |
| Other | 0 | | | | (1.8) | | |
| | $ | (.2) | | | | $ | (87.9) | | |
| | | | $ | (9.4) | | | $ | (9.1) | |
Condensed Consolidated Statements of Operations Information
Other, net, consisted of the following (in millions):
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | | | Predecessor | | | | |
| Three Months Ended March 31, 2022 | | | | | Three Months Ended March 31, 2021 | | |
| Net foreign currency exchange gains | $ | 4.7 | | | | | | $ | 16.6 | | | | | |
| Net periodic pension income, excluding service cost | 4.0 | | | | | | 4.0 | | | | | |
| | | | | | | | | | |
| Net gain on sale of property | 2.5 | | | | | | 1.4 | | | | | |
| Other income (expense) | (0.2) | | | | | | 0.5 | | | | | |
| $ | 11.0 | | | | | | $ | 22.5 | | | | | |
Condensed Consolidated Statement of Cash Flows Information
Our restricted cash of $53.1$30.0 million and $35.9 million at June 30,March 31, 2022 and December 31, 2021, respectively, consists primarily of approximately $37.4$27.1 million for theand $31.1 million of collateral on letters of credit and approximately $11.4 million in escrow for payment of professional fees related to the reorganization. See" each respective period. See "Note 1411 - Contingencies" for more information regarding our letters of credit.
Concentration of Risk
We are exposed to credit risk relating to our receivables from customers, and our cash and cash equivalents.equivalents and, at times, investments. 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 customerwith customers that individually contributed 10% or more of revenue were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | | | |
| Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2020 | | |
BP(1) | 9 | % | | | 11 | % | | 11 | % | | | | |
| | | | | | | | | | |
Total(2) | 0 | % | | | 0 | % | | 5 | % | | | | |
Woodside Energy(3) | 0 | % | | | 0 | % | | 12 | % | | | | |
| Other | 91 | % | | | 89 | % | | 72 | % | | | | |
| 100 | % | | | 100 | % | | 100 | % | | | | |
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor |
| Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 |
BP(1) | 9 | % | | | 14 | % | | 9 | % |
| | | | | | |
Total(2) | 0 | % | | | 0 | % | | 11 | % |
Woodside Energy(3) | 0 | % | | | 0 | % | | 7 | % |
| Other | 91 | % | | | 86 | % | | 73 | % |
| 100 | % | | | 100 | % | | 100 | % |
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | | | Predecessor | | | | |
| Three Months Ended March 31, 2022 | | | | | Three Months Ended March 31, 2021 | | |
BP plc ("BP")(1) | 16 | % | | | | | 15 | % | | | | |
Shell plc ("Shell")(2) | 11 | % | | | | | 9 | % | | | | |
Eni S.p.A ("Eni")(3) | 10 | % | | | | | 7 | % | | | | |
| Other | 63 | % | | | | | 69 | % | | | | |
| 100 | % | | | | | 100 | % | | | | |
(1)During the twothree months ended June 30, 2021, 25%March 31, 2022 (Successor), 43% of the revenues provided by BP were attributable to our Floaters segment, 13% of the revenues were attributable to our Jackups segment and the remaining were attributable to our managed rigs. During one month and four months ended April 30, 2021, 7% and 37% of the revenue provided by BP were attributable to our Floaters segment respectively, 28% and 17% of the revenue were attributable to our Jackup segment respectively, and the remaining were attributable to our managed rigs.
During the three months ended June 30, 2020, 17%March 31, 2021 (Predecessor), 43% of the revenues provided by BP were attributable to our JackupsFloaters segment, 39%15% of the revenues were attributable to our Floaters segment and the remaining were attributable to our managed rigs. During the six months ended June 30, 2020, 20% of the revenue provided by BP were attributable to our Jackup segment, 27% of the revenue were attributable to our FloaterJackups segment and the remaining were attributable to our managed rigs.
(2)During the three and six months ended June 30, 2020, 56% and 82%March 31, 2022 (Successor), 67% of the revenues provided by TotalShell were attributable to theour Floaters segment and 33% of the remainingrevenues were attributable to theour Jackups segment.
During the three months ended March 31, 2021 (Predecessor), 62% of the revenues provided by Shell were attributable to our Floaters segment and 38% of the revenues were attributable to our Jackups segment.
(3)During the three and six months ended June 30, 2020, allMarch 31, 2022 (Successor), 58% of the revenuerevenues provided by Woodside EnergyEni were attributable to our Jackups segment and 42% of the revenues were attributable to our Floaters segment.
During the three months ended March 31, 2021 (Predecessor), 69% of the revenues provided by Eni were attributable to our Floaters segment and 31% of the revenues were attributable to our Jackups segment.
For purposes of our geographic disclosure, we attribute revenues to the geographic location where such revenues are earned. Consolidated revenues by region werefor locations that individually had 10% or more of revenue are as follows (in millions):
| | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | | | |
| Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2020 | | |
United Kingdom(1) | $ | 41.1 | | | | $ | 19.6 | | | $ | 52.8 | | | | | |
Norway(1) | 40.5 | | | | 19.3 | | | 46.5 | | | | | |
U.S. Gulf of Mexico(2) | 30.9 | | | | 17.6 | | | 66.6 | | | | | |
Saudi Arabia(3) | 25.2 | | | | 12.0 | | | 57.3 | | | | | |
Mexico(4) | 18.9 | | | | 6.1 | | | 22.7 | | | | | |
| | | | | | | | | | |
Australia(5) | 17.8 | | | | 0.9 | | | 72.3 | | | | | |
| Other | 28.4 | | | | 14.8 | | | 70.6 | | | | | |
| $ | 202.8 | | | | $ | 90.3 | | | $ | 388.8 | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | | | |
| Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 | | |
United Kingdom(1) | $ | 41.1 | | | | $ | 75.7 | | | $ | 105.3 | | | | | |
Norway(1) | 40.5 | | | | 73.3 | | | 87.5 | | | | | |
U.S. Gulf of Mexico(2) | 30.9 | | | | 74.4 | | | 145.3 | | | | | |
Saudi Arabia(3) | 25.2 | | | | 53.6 | | | 141.2 | | | | | |
Mexico(4) | 18.9 | | | | 44.3 | | | 38.7 | | | | | |
| | | | | | | | | | |
Australia(5) | 17.8 | | | | 1.0 | | | 98.3 | | | | | |
| Other | 28.4 | | | | 75.1 | | | 229.1 | | | | | |
| $ | 202.8 | | | | $ | 397.4 | | | $ | 845.4 | | | | | |
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | | | Predecessor | | | | |
| Three Months Ended March 31, 2022 | | | | | Three Months Ended March 31, 2021 | | |
United Kingdom(1) | $ | 65.6 | | | | | | $ | 56.1 | | | | | |
U.S. Gulf of Mexico(2) | 50.6 | | | | | | 56.8 | | | | | |
Saudi Arabia(3) | 38.1 | | | | | | 41.6 | | | | | |
Norway(1) | 24.3 | | | | | | 54.0 | | | | | |
Mexico(4) | 22.1 | | | | | | 38.2 | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| Other | 117.7 | | | | | | 60.4 | | | | | |
| $ | 318.4 | | | | | | $ | 307.1 | | | | | |
(1)During the twothree months ended June 30,March 31, 2022 (Successor) and 2021 one month and four months ended April 30, 2021 and three and six months ended June 30, 2020, all(Predecessor), revenues earned in the United Kingdom and Norway were attributable to our Jackups segment.
(2)During the twothree months ended June 30, 2021, 56%March 31, 2022 (Successor), 41% and 13% of the revenues earned in U.S. Gulf of Mexico were attributable to our Floaters segment. During the one monthsegment and four months ended April 30, 2021, 62% and 64% of the revenue earned in U.S. Gulf of Mexico were attributable to our FloatersJackups segment respectively. The remaining revenues were attributable to our managed rigs.
During the three months ended June 30, 2020, 66%March 31, 2021 (Predecessor), 65% of the revenues earned in U.S. Gulf of Mexico were attributable to our Floaters segment 6% were attributable to our Jackups segment and the remaining revenues were primarily attributable to our managed rigs. During the six months ended June 30, 2020, 61% of the revenues earned in U.S. Gulf of Mexico were attributable to our Floaters segment, 12% were attributable to our Jackups segment and the remaining revenues were attributable to our managed rigs
(3)During the twothree months ended June 30, 2021, 57%March 31, 2022 (Successor), 62% of the revenues earned in Saudi Arabia were attributable to our Jackups segment. During the one month and four months ended April 30, 2021, 55% and 57% of theThe remaining revenues earned in Saudi Arabia were attributable to our JackupsOther segment respectively. and relates primarily to our rigs leased to ARO.
During the three and six months ended June 30, 2020, 62% andMarch 31, 2021 (Predecessor), 57% of the revenues earned in Saudi Arabia were attributable to our Jackups segment. The remaining revenues were attributable to our Other segment and relates primarily to our rigs leased to ARO.
relates to our rigs leased to ARO and certain revenues related to our Transition Services Agreement and Secondment Agreement.
(4)During the twothree months ended June 30,March 31, 2022 (Successor), 93% of the revenues earned in Mexico were attributable to our Jackups segment and the remaining revenues were attributable to our Floaters segment.
During the three months ended March 31, 2021 41% and 59%(Predecessor), 56% of the revenues earned in Mexico were attributable to our Floaters segment and Jackups segment respectively. During the one month and four months ended April 30, 2021, 4% and 49% of theremaining revenues earned Mexico were attributable to our Floaters segment, respectively, and 96% and 51% of the revenue earned in Mexico were attributable to our Jackups segment respectively. During the three and six months ended June 30, 2020, 35% and 58% revenue earned in Mexico were attributable to our Floaters segment respectively, 65% and 42% revenue earned in Mexico were attributable to our Jackups segment respectively.segment.
(5)During two months ended June 30, 2021, 58% and 42% revenues earned in Australia were attributable to our Floaters and Jackups segment respectively. During the one month and four months ended April 30, 2021, 78% and 77% revenues earned in Australia were attributable to Floaters segment respectively, 22% and 23% revenues earned in Australia were attributable to Jackups segment respectively. During the three and six months ended June 30, 2020, 100% and 89% of the revenue earned in Australia were attributable to our Floater segment, and the remaining revenues attributable to our Jackups segment.
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 and related notes thereto included in "Item 1. Financial Statements" and with our annual report on Form 10-K for the year ended December 31, 2020.2021. 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 2021, weWe currently own an offshore drilling rig fleet of 6053 rigs, with drilling operations in almost every major offshore market across fivesix continents. Our rig fleet includes 11 drillships, four dynamically positioned semisubmersible rigs, one moored semisubmersible rig, 4437 jackup rigs and a 50% equity interest in Saudi Aramco Rowan Offshore Drilling Company ("ARO"),ARO, our 50/50 unconsolidated joint venture with Saudi Aramco, which owns an additional seven rigs. Additionally, we have options to purchase two additional recently constructed drillships on or before December 31, 2023. We operateown 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, Emergence from Chapter 11 Bankruptcy and Fresh Start Accounting
On August 19, 2020 (the “Petition Date”"Petition Date"), Valaris plc (“Legacy Valaris” or “Predecessor”) and certain of its direct and indirect subsidiaries (collectively, the “Debtors”) filed voluntary petitions for reorganization under chapter 11 of the Bankruptcy Code in the Bankruptcy Court underfor the caption In re Valaris plc, et al., Case No. 20-34114 (MI)Southern District of Texas (the “Chapter"Chapter 11 Cases”Cases").
In connection with the Chapter 11 Cases and the plan of reorganization, on and prior to April 30, 2021 (the "Effective("Effective Date"), the CompanyLegacy Valaris effectuated certain restructuring transactions, pursuant to which Valaris Limited ("Valaris") was formed and, through a series of transactions, Legacy Valaris transferred to a subsidiary of Valaris substantially all of the subsidiaries, and other assets, of Legacy Valaris.
On the Effective Date, we successfully completed our financial restructuring and together with the Debtors emerged from the Chapter 11 Cases. Upon emergence from the Chapter 11 Cases, we eliminated $7.1 billion of debt and obtained a $520.0 million capital injection by issuing the First Lien Notes. See “Note 11 - Debt" for additional information on the First Lien Notes. On the Effective Date.Date, Legacy Valaris Class A ordinary shares were cancelled and the Valaris common shares of Valaris with a nominal value of $0.01 per share (“Common Shares”(the "Common Shares") were issued. Also, former holders of Legacy Valaris' equity were issued warrants (the "Warrants") to purchase Common Shares.. See “Note 12 - Shareholders' Equity" for additional information on the issuance of the Common Shares and Warrants.Shares.
References to the financial position and results of operations of the "Successor" or "Successor Company" relate to the financial position and results of operations of the CompanyValaris, together with its consolidated subsidiaries, after the Effective Date. References to the financial position and results of operations of the "Predecessor" or "Predecessor Company" refer to the financial position and results of operations of Legacy Valaris, together with its consolidated subsidiaries, on and prior to the Effective Date. References to the “Company,” “we,” “us” or “our” in this Quarterly Report are to Valaris, together with its consolidated subsidiaries, when referring to periods following the Effective Date, and to Legacy Valaris, together with its consolidated subsidiaries, when referring to periods prior to and including the Effective Date.
Upon emergence fromOn the Chapter 11 Cases,Effective Date, we qualified for and adoptedapplied fresh start accounting. The application of fresh start accounting resulted in a new basis of accounting, and the Companywe became a new entity for financial reporting purposes. Accordingly, our financial statements and notes after the Effective Date are not comparable to our financial statements and notes on and prior to that date. The condensed consolidated financial statements and notes have been presented with a black line division to delineate the lack of comparability between the Predecessor and Successor.
See“Note 2 – Chapter 11 Proceedings” and "Note 3 - Fresh Start Accounting" for additional details regarding the bankruptcy, our emergence and fresh start accounting.
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 somewhat between regions, significant variations between most regions 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 flexibility within our capital 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 shorten the duration of many of our 2020 drilling contracts, cancel future drilling programs and seek pricing and other contract concessions which led to material operating losses and liquidity constraints for us.
In 2020, the combined effects of the global COVID-19 pandemic, the significant decline in the demand for oil and the substantial surplus in the supply of oil resulted in significantly reduced demand and day rates for offshore drilling provided by the Company and increased uncertainty regarding long-term market conditions. These events had a significant adverse impact on our current and expected liquidity position and financial runway and led to the filing of the Chapter 11 Cases.
By the middle ofIn 2021, Brent crude oil prices climbed back to pre-COVID-19 pandemic levels, toincreased from approximately $73$50 per barrel in June 2021, and we observed a slight increase in customer tendering activity for both floaters and jackupsat the beginning inof the latter part of 2020. In early July 2021, rising global demand for oil and continuing disputes about supply levels among members of OPEC+ sent Brent crude oil prices above $75 per barrel. Later in July 2021, the members of OPEC+ agreedyear to phase out 5.8 million barrels of oil per day of oil production cuts by September 2022, effectively undoing production cuts put in place in response to the COVID-19 pandemic. After a brief decline following the announcement, oil prices returned to $74nearly $80 per barrel by the end of July.the year. Increased oil prices were due to, among other factors, rebounding demand for hydrocarbons, a measured approach to production increases by OPEC+ members and a focus on cash flow and returns by major exploration and production companies. The constructive oil price environment has led to an improvement in contracting and tendering activity in 2021 as compared to 2020. Benign environment floater rig years awarded in the first half of 2021 were nearly double that in the first half of 2020 and jackup rig years awarded increased by 15% when comparing the same periods. This increase in activity is particularly evident for drillships with several multi-year contracts awarded year to date. 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.
Additionally,In 2022, Brent crude oil prices have increased dramatically and become increasingly volatile, in large part due to Russia’s invasion of Ukraine, which led to sanctions being placed on Russia, including its ability to export crude oil and other petroleum products. The anticipated impact on supply drove Brent crude oil prices above $130 per barrel in early March. As of March 31, 2022, the spot Brent crude price had declined to approximately $108 per barrel. However, volatility remains high.
While the spot market for crude oil is indicative of current market conditions, for larger offshore projects, our customers are more focused on medium-term and long-term commodity prices when making investment decisions. These forward prices have also reached levels that are constructive for offshore projects.
The full impact that the pandemic and the volatility of oil prices will have on our results of operations, financial condition, liquidity and cash flows is uncertain due to numerous factors, including the duration and severity of the pandemic, the continued development, availability and effectiveness of the ongoing vaccine rollout, the general resumption of global economic activity along with the injection of substantial government monetary and fiscal stimulus, inflation and the sustainability of the improvements in oil prices and demand in the face of market volatility. To date, the COVID-19 pandemic has resulted in only limited operational downtime. OurWhile we have seen improvement in recent months, 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 subject 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.
WeMore recently, we have begun to feel the impacts of global inflation, both in increased personnel costs as well as in the prices of goods and services required to operate our rigs. While we are currently unable to estimate the ultimate impact of rising prices, we do expect that these challengesour costs will continue to rise in the near term and will impact our profitability. While certain of our long-term contracts contain provisions for escalating costs, we cannot predict with certainty our ability to successfully claim recoveries of higher costs from our customers under these contractual stipulations.
The near-term outlook for the offshore drilling contractorsindustry has improved since the beginning of 2021, as customers wait to gain additional clarity onevidenced by improving global utilization and increasing day rates for offshore drilling rigs, most notably for drillships. However, heightened geopolitical tensions have increased volatility, inflation is increasing costs of operations and the global recovery from the COVID-19 pandemic remains uncertain. As a result, there is still uncertainty around the sustainability of improved commodity pricing. We believe the current marketimprovement in oil prices and macro-economic conditions will continue to create a challenging contracting environment through 2021, into 2022the recovery in demand for, and potentially beyond.profitability of, offshore drilling services.
Backlog
Our backlog was $2.2$2.5 billion and $1.0$2.4 billion as of AugustMay 2, 20212022 and December 31, 2020, respectively.February 21, 2022, respectively, as recent contract awards and contract extensions were offset by revenues realized. Our backlog excludes ARO's backlog but includes backlog of $31.1$140.1 million and $74.7$134.3 million, respectively, from our rigs leased to ARO at the contractual rates. Contract rates with ARO are subject to adjustment resulting from the shareholder agreement.agreement governing the joint venture. See "Note 53 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information. The increase
Approximately $428 million of backlog as of May 2, 2022 is attributable to backlog is dueour contract awarded to recentVALARIS DS-11 for an eight-well contract awardsfor a deepwater project in the U.S. Gulf of Mexico expected to commence in mid-2024. In February 2022, the customer decided not to sanction and therefore withdrew from the project associated with this contract. In March 2022, the contract extensions, partially offset by revenues realized. As revenues are realized and if we experiencewas novated to another customer, which was a partner on the project. No material changes to the contract cancellations, we may experience declinesresulted from the novation, including with respect to the termination provisions in backlog, which would result in a decline in revenues and operating cash flows over the near-term.event the project does not receive final investment decision (FID).
ARO backlog was $953.2 million and $347.5 million$1.5 billion as of Augustboth May 2, 20212022 and December 31, 2020, respectively,February 21, 2022, inclusive of backlog on both ARO owned rigs and rigs leased from us. The increase in backlog is due to contracts awarded to five ARO owned rigs during the first quarter.us, as a recent contract award was offset by revenues realized. As a 50/50 unconsolidated joint venture, when ARO realizes revenue from its backlog, 50% of the earnings thereon would be reflected in our results.results in the equity in earnings of ARO in our Condensed Consolidated Statement of Operations. The earnings from ARO backlog with respect to rigs leased from us will be net of, among other things, payments to us under bareboat charters for those rigs.
See “Item 1A. – Risk Factors” for risks related to the realization of our backlog.
BUSINESS ENVIRONMENT
Floaters
TheStarting in 2021, the more constructive oil price environment has led to an improvement in contracting and tendering activity. Benign floater contracting environment remains challenging due to limited demandrig years awarded in 2021 were more than double the amount awarded in 2020. This increase in activity is particularly evident for drillships with several multi-year contracts awarded and excess supply. Floater demand declined materiallya meaningful improvement in March and April 2020, as our customers reduced capital expenditures particularlyday rates for capital-intensive, long-lead deepwater projectsthis class of assets. As a result, we are currently in the wakeprocess of oil price declines from around $60 per barrel at year-end 2019reactivating three drillships and recently completed the reactivation of one semisubmersible, each in preparation for long-term contracts expected to around $20 per barrel in mid-April 2020. This caused our customers, primarilycommence in the second and third quartersquarter of 2020,2022.
While we expect the improved oil price environment to cancel or delay drilling programs,continue to terminate drilling contractssupport deepwater investments, heightened geopolitical tensions, including Russia's invasion of Ukraine, have increased volatility, 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, anduncertain. As a result, there is still a significant amount of uncertainty around the sustainability of the improvement in oil prices to support aand the recovery in demand for offshore drilling services.
Our backlog for our floater segment was $1.4$1.7 billion and $163.7(including approximately $428 million for the VALARIS DS-11 discussed above) as of Augustboth May 2, 20212022 and December 31, 2020, respectively. The increase in our backlog was due to the addition of backlog from newFebruary 21, 2022, as recent contract awards and contract extensions partiallywere offset by revenues realized.
Utilization for our floaters was 22%25% during the secondfirst quarter of 2022 compared to 28% in the fourth quarter of 2021 compareddue to 29%special periodic survey work required in the first quarter of 2021.2022. Average day rates were approximately $197,000 during the secondfirst quarter of 20212022 compared to approximately $198,000$189,000 in the fourth quarter of 2021. The increase in average day rate is the result of integrated services provided to certain customers in the first quarter of 2022 as well as lower rates resulting from weather conditions in the fourth quarter of 2021.
ThereGlobally, there are approximately 2119 newbuild drillships and benign environment semisubmersible rigs reported to be under construction, of which five are scheduled to be delivered before the end of 2021.2022. Most newbuild floaters are uncontracted. Several newbuild deliveries have been delayed into future years, and we expect that more uncontracted newbuilds willmay be delayed or cancelled.
Drilling contractors have retired approximately 130136 benign environment floaters since the beginning of 2014. SixEight benign environment floaters older than 20 years of age are currently idle, eightfour 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 1512 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 likelymay elect to scrap or cold-stack some or allcold stack a portion of these rigs. Improvements
A sustained constructive oil price environment and improvement in demand and/or reductions in supply will befor offshore projects are necessary before meaningful increases into maintain the improving floater utilization and day rates are realized.rate trajectory.
Jackups
During 2020,While the demand for jackups declined during 2020 as a result of the combined impacts of the COVID-19 pandemic as well as the oil supply and demand imbalance, the decline was not as significant as it was for floaters. As such, with recent improvements in oil prices, we are experiencing incremental contracting activity, but at a pace slower than that for floaters. With much of the anticipated demand for jackups coming from infill drilling of existing fields, we expect that this demand will remain more stable 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 improvementchanges in oil prices to support a recovery in demand for offshore drilling services.prices.
Our backlog for our jackup segment was $767.2$515.2 million and $737.6$643.0 million as of AugustMay 2, 20212022 and December 31, 2020,February 21, 2022, respectively. The increasedecrease in our backlog was due to revenues realized partially offset by the addition of backlog from new contract awards and contract extensions, partially offset by revenues realized.extensions.
Utilization for our jackups was 54%63% during the secondfirst quarter of 2022 compared to 50%55% in the fourth quarter of 2021 as new jackup contracts commenced or had a full quarter of operations in the first quarter of 2021.2022. Average day rates were approximately $99,000$89,000 during the second quarter compared to approximately $95,000 in the first quarter of 2022 compared to approximately $90,000 in the fourth quarter of 2021.
While operating days increased across the jackup fleet, certain higher specification jackups rolled off contract resulting in an overall decline in the average day rate.
ThereGlobally, there are approximately 3428 newbuild jackup rigs reported to be under construction, of which 1218 are scheduled to be delivered before the end of 2021.2022. 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 140162 jackups since the beginning of the downturn. Approximately 8061 jackups older than 30 years are currently idle, 3024 jackups that are 30 years or older have contracts expiring within the next six months without follow-on work, and there are a further 6515 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-stackcold stack these rigs. We expect jackup scrapping
A sustained constructive oil price environment and cold-stacking to continue for the remainder of 2021. Improvementsimprovement in demand and/or reductions in supply will befor offshore projects are necessary before meaningful increases into maintain the improving jackup utilization and day rates are realized.rate trajectory, which has been at a slower pace than that of floaters.
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
Indenture dated April 30, 2021 that governs our First Lien Notes
(the “Indenture”), 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 rig brokers to market certain rigs. See “Note 8– Debt" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information on restrictions on the sales of assets.
Subsequent to March 31, 2022, we reached an agreement for the sale of VALARIS 113 and VALARIS 114, resulting in an expected pre-tax gain on sale to be recorded in the second quarter of 2022 of approximately $120 million.
RESULTS OF OPERATIONS
We are not ableManagement believes the comparison of the most recently completed quarter to compare the immediately preceding quarter provides more relevant information needed to understand and analyze the business. As such, as permitted under applicable SEC rules, we have elected to discuss any material changes in our results of operations forby including a comparison of our most recently completed fiscal quarter ended March 31, 2022 (the "current quarter") (Successor) to the monthimmediate preceding fiscal quarter ended April 30,December 31, 2021 (Successor) (the “Q2 Predecessor Period”"preceding quarter") and four-month period ended April 30, 2021 (the “H1 Predecessor Period” and, together with the Q2 Predecessor Period, the “2021 Predecessor Periods”). We also continue to discuss any of the previous periods reportedmaterial changes in the condensed consolidated financial statements, and we do not believe reviewing this period in isolation would be useful in identifying any trends in or reaching any conclusions regarding our overall operating performance. We believe that the discussion of our results of operations for the two-months ended June 30, 2021 (the “Successor Period”) combined with the 2021 Predecessor Periods provide more meaningful comparisonscurrent quarter compared to the comparable periods in 2020 and are more useful in understanding operational trends. These combined results do not comply with GAAP and have not been preparedcorresponding period of the preceding fiscal year (Predecessor) (the "prior year quarter"), as pro forma resultsrequired under the applicable SEC rules, but are presented because we believe they provide the most meaningful comparison of our results to prior periods.rules.
The following table summarizes our Condensed Consolidated Results of Operations (in millions):
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | Combined (Non-GAAP) | | Predecessor |
| Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2021 | | Three Months Ended June 30, 2020 |
| Revenues | $ | 202.8 | | | | $ | 90.3 | | | $ | 293.1 | | | $ | 388.8 | |
| Operating expenses | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 168.7 | | | | 85.6 | | | 254.3 | | | 370.7 | |
| Loss on impairment | — | | | | — | | | — | | | 838.0 | |
| Depreciation | 16.6 | | | | 37.5 | | | 54.1 | | | 131.5 | |
| General and administrative | 12.7 | | | | 6.4 | | | 19.1 | | | 62.6 | |
| Total operating expenses | 198.0 | | | | 129.5 | | | 327.5 | | | 1,402.8 | |
| | | | | | | | |
| Equity in earnings (losses) of ARO | 4.8 | | | | 1.2 | | | 6.0 | | | (5.2) | |
| Operating income (loss) | 9.6 | | | | (38.0) | | | (28.4) | | | (1,019.2) | |
| Other income (expense), net | 1.4 | | | | (3,533.7) | | | (3,532.3) | | | (105.4) | |
| Provision (benefit) for income taxes | 15.1 | | | | (15.5) | | | (0.4) | | | (15.8) | |
| Net loss | (4.1) | | | | (3,556.2) | | | (3,560.3) | | | (1,108.8) | |
| Net income (loss) attributable to noncontrolling interests | (2.1) | | | | (.8) | | | (2.9) | | | 1.4 | |
| Net loss attributable to Valaris | $ | (6.2) | | | | $ | (3,557.0) | | | $ | (3,563.2) | | | $ | (1,107.4) | |
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | Combined (Non-GAAP) | | Predecessor |
| Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Month Ended June 30, 2021 | | Six Months Ended June 30, 2020 |
| Revenues | $ | 202.8 | | | | $ | 397.4 | | | $ | 600.2 | | | $ | 845.4 | |
| Operating expenses | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 168.7 | | | | 337.8 | | | 506.5 | | | 846.7 | |
| Loss on impairment | — | | | | 756.5 | | | 756.5 | | | 3,646.2 | |
| Depreciation | 16.6 | | | | 159.6 | | | 176.2 | | | 296.0 | |
| General and administrative | 12.7 | | | | 30.7 | | | 43.4 | | | 116.0 | |
| Total operating expenses | 198.0 | | | | 1,284.6 | | | 1,482.6 | | | 4,904.9 | |
| | | | | | | | |
| Equity in earnings (losses) of ARO | 4.8 | | | | 3.1 | | | 7.9 | | | (11.5) | |
| Operating income (loss) | 9.6 | | | | (884.1) | | | (874.5) | | | (4,071.0) | |
| Other income (expense), net | 1.4 | | | | (3,563.5) | | | (3,562.1) | | | (213.3) | |
| Provision (benefit) for income taxes | 15.1 | | | | 16.2 | | | 31.3 | | | (167.8) | |
| Net loss | (4.1) | | | | (4,463.8) | | | (4,467.9) | | | (4,116.5) | |
| Net income (loss) attributable to noncontrolling interests | (2.1) | | | | (3.2) | | | (5.3) | | | 2.8 | |
| Net loss attributable to Valaris | $ | (6.2) | | | | $ | (4,467.0) | | | $ | (4,473.2) | | | $ | (4,113.7) | |
Overview
Revenues decreased $95.7 million, or 25%, for the combined Successor and Predecessor results for the three months ended June 30,March 31, 2022 (Successor), three months ended December 31, 2021 (Successor) and three months ended March 21, 2021 (Predecessor) (in millions):
| | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | | | | | | | Predecessor |
| Three Months Ended March 31, 2022 | | Three Months Ended December 31, 2021 | | | | | | | | | | Three Months Ended March 31, 2021 |
| Revenues | $ | 318.4 | | | $ | 305.5 | | | | | | | | | | | $ | 307.1 | |
| Operating expenses | | | | | | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 331.3 | | | 285.5 | | | | | | | | | | | 253.6 | |
| Loss on impairment | — | | | — | | | | | | | | | | | 756.5 | |
| Depreciation | 22.5 | | | 25.1 | | | | | | | | | | | 122.1 | |
| General and administrative | 18.8 | | | 18.3 | | | | | | | | | | | 24.3 | |
| Total operating expenses | 372.6 | | | 328.9 | | | | | | | | | | | 1,156.5 | |
| | | | | | | | | | | | | |
| Equity in earnings (losses) of ARO | 4.3 | | | (1.3) | | | | | | | | | | | 1.9 | |
| Operating loss | (49.9) | | | (24.7) | | | | | | | | | | | (847.5) | |
| Other income (expense), net | 9.4 | | | 21.4 | | | | | | | | | | | (28.4) | |
| Provision (benefit) for income taxes | (0.7) | | | (31.0) | | | | | | | | | | | 31.7 | |
| Net income (loss) | (39.8) | | | 27.7 | | | | | | | | | | | (907.6) | |
| Net (income) loss attributable to noncontrolling interests | 1.2 | | | — | | | | | | | | | | | (2.4) | |
| Net income (loss) attributable to Valaris | $ | (38.6) | | | $ | 27.7 | | | | | | | | | | | $ | (910.0) | |
Overview
Revenue increased $12.9 million, or 4%, for the current quarter as compared to the preceding quarter, primarily due to $8.1 million from higher average day rates from certain rigs and $4.7 million from higher customer reimbursable revenues. This increase was partially offset by $3.7 million from fewer operating days from certain rigs.
Revenues increased $11.3 million, or 4%, for the current quarter as compared to the prior year quarter, primarily due to $64.1$18.3 million from fewerincreased operating days under contract across our fleet, $46.3 million due to termination fees received for certain rigs in the prior year quarter, $14.1and $11.8 million from the sale of VALARIS JU-84, VALARIS JU-87higher customer reimbursable revenue. This increase was partially offset by $13.6 million from lower average day rates and VALARIS JU-101 which operated in the prior year quarter, and $4.0$2.4 million due to lower revenues earned under the Lease Agreements and Secondment Agreement with ARO. This decline was partially offset by a $33.5 million increase in revenue for certain rigs with higher average day rates for the combined three months ended June 30, 2021 as compared to the prior year quarter.
Revenues decreased $245.2 million, or 29%, for the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period primarily due to $188.1 million from fewer days under contract across our fleet, $47.4 millionresulting from the saleretirement of VALARIS 5004, VALARIS JU-84, VALARIS JU-87, VALARIS JU-88 and VALARIS JU-101 which operated intwo rigs at the prior year quarter, $46.3 million dueend of 2021 that were leased to termination fees receivedARO for certain rigs in prior year period, and $29.9 million due to lower revenues earned undermuch of the Secondment Agreement, Lease Agreements and Transition Services agreement with ARO. This decline was partially offset by a $58.5 million increase in revenue for certain rigs with higher average day rates for the combined six months ended June 30, 2021 as compared to the prior year period.year.
Contract drilling expense decreased $116.4increased $45.8 million, or 16%, for the current quarter as compared to the preceding quarter, primarily due to a $24.3 million increase in reactivation costs compared to the preceding quarter, an $8.3 million increase in personnel costs and a $6.5 million increase in reimbursable expenses.
Contract drilling expense increased $77.7 million, or 31%, for the combined Successor and Predecessor results for the three months ended June 30, 2021,current quarter as compared to the prior year quarter, primarily due to $84.3a $50.3 million increase in reactivation costs, a $13.8 million increase in reimbursable expenses, a $12.1 million increase in personnel costs and a $6.8 million increase in mobilization costs. These increases were partially offset by $5.8 million of lower costcosts on idle rigs, $28.0 million from rigs sold between the comparative periods, and reduced cost resulting primarily from spend control efforts.
Contract drilling expense decreased $340.2 million, or 40%, for the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period primarily due to $193.2 million of lower cost on idle rigs, $52.5 million from rigs sold between the comparative periods, and reduced cost resulting primarily from spend control efforts. Additionally, there was a decline of $18.6 million related to the Secondment Agreement with ARO as almost all remaining seconded employees became employees of ARO during the second quarter of 2020.rigs.
During the secondprior year quarter, of 2020, we recorded non-cash losses on impairment totaling $838.0$756.5 million, with respect to certain assets in our fleet. See "Note 75 - Property and Equipment" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information.
During the four months ended April 30, 2021 and the six months ended June 30, 2020, we recorded non-cash losses on impairment totaling $756.5 million and $3.6 billion, respectively, with respect to certain assets in our fleet. See "Note 7 - Property and Equipment" for additional information.
Depreciation expense decreased $77.4$99.6 million, or 59%82%, for the combined Successor and Predecessor results for the three months ended June 30, 2021current quarter as compared to the prior year quarter, primarily due to the reduction in values of property and equipment from the application of fresh start accounting.accounting on the Effective Date.
Depreciation expense decreased $119.8 million, or 40%, for the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period primarily due to reduction in values of property and equipment from the application of fresh start accounting and 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 $43.5$5.5 million, or 69%, and $72.6 million or 63%23%, for the combined Successor and Predecessor results for the combined Successor and Predecessor results for the three and six months ended June 30, 2021, respectively,current quarter as compared to the prior year comparative periods. The decline isquarter, primarily due to a change in incentive compensation structure following the Effective Date.
Other income, net, decreased $12.0 million for the current quarter as compared to the preceding quarter, primarily due to the decrease in gains on the sale of assets of $18.5 million partially offset by a $3.9 million decrease in reorganization costs incurred directly related to charges in the prior year periods for professional fees incurred in relation to the Chapter 11 Cases, but
prior to the Petition Date, professional fees associated with shareholder activism defense, organizational change initiatives, as well as merger integration related costs.Cases.
Other expense,income, net, increased $3,426.9 million and $3,348.8$37.8 million for the combined Successor and Predecessor results for the three and six months ended June 30, 2021, respectively,current quarter as compared to the prior year comparative periods,quarter, primarily due to a $51.2 million reduction in reorganization itemscosts incurred in the current year directly related to the Chapter 11 Cases. See“Note 2– Chapter 11 Proceedings” for details relatedCases and an $8.3 million increase to reorganization items.interest income primarily due to the amortization of the discount on the note receivable from ARO. This increase wasis partially offset by a reductionan $11.9 million decrease in foreign currency gains as well as an increase in interest expense asof $10.2 million. The higher interest expense is related to our First Lien Notes in the first quarter of 2022 whereas in the prior year quarter we had discontinued accruing interest on our outstanding predecessor debt after the Petition Date.
Rig Counts, Utilization and Average Day Rates
The following table summarizes our and ARO's offshore drilling rigs as of June 30,March 31, 2022 and December 31, 2021 (Successor) and 2020:March 31, 2021 (Predecessor):
| | | | 2021 | | 2020 | | March 31, 2022 | | December 31, 2021 | | March 31, 2021 |
Floaters(1) | Floaters(1) | 16 | | 17 | Floaters(1) | 16 | | 16 | | 16 |
Jackups(2)(1) | Jackups(2)(1) | 34 | | 39 | Jackups(2)(1) | 31 | | 33 | | 36 |
Other(3)(2) | Other(3)(2) | 9 | | 9 | Other(3)(2) | 8 | | 7 | | 9 |
Held-for-sale(2)(4) | 1 | | 7 | |
| | Total Valaris | Total Valaris | 60 | | 72 | Total Valaris | 55 | | 56 | | 61 |
Valaris - Under construction(5) | 2 | | 2 | |
| ARO(6)(3) | ARO(6)(3) | 7 | | 7 | ARO(6)(3) | 7 | | 7 | | 7 |
ARO - Under construction (7) | 2 | | 2 | |
|
(1)During the second, third and fourth quarter of 2020, we sold VALARIS 8504.
(2)During the third quarter of 2020, we sold VALARIS JU-87 and during the fourth quarter of 2020, we sold VALARIS JU-84 and VALARIS JU-88. During the second quarterquarters of 2021, we sold VALARIS 101, and classified VALARIS 100 as held-for-sale.and VALARIS 142, respectively. During the first quarter of 2022, we sold VALARIS 67 and leased VALARIS 140 to ARO.
(3)(2)This represents the ninejackup 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 thirdfourth quarter of 2020,2021, we sold VALARIS 8500,22 and VALARIS 8501,37, which were previously leased to ARO. During the first quarter of 2022, VALARIS 8502, VALARIS DS-3, VALARIS DS-5, VALARIS DS-6 and JU-105.140 was leased to ARO.
(5)We have an option to take delivery of VALARIS DS-13 and VALARIS DS-14, on or before December 31, 2023. The purchase price for the rigs are estimated to be approximately $119.1 million and $218.3 million, respectively, 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 we elect not to purchase the rigs, we have no further obligations to the shipyard.
(6)(3)This represents the seven jackup rigs owned by ARO which are operating under long-term contracts with Saudi Aramco.
(7)
We provide management services in the U.S. Gulf of Mexico on two rigs owned by a third-party not included in the table above.
During 2020,
We are a party to contracts whereby we have the option to take delivery of two recently constructed drillships that are not included in the table above.
Additionally, ARO has ordered two jackups which are under construction in the Middle East that are not included in the table above. These newbuild jackup rigs scheduled for deliveryare expected to be delivered in 2022.the first or second quarter of 2023.
The following table summarizes our and ARO's rig utilization and average day rates by reportable segment were as follows (in millions):segment:
| | | Three Months Ended June 30, | | Six Months Ended June 30, | | | | | | | | | | | | | | | | | | |
| | 2021 | | 2020 | | 2021 | | 2020 | | Three Months Ended March 31, 2022 | | Three Months Ended December 31, 2021 | | | Three Months Ended March 31, 2021 | |
Rig Utilization(1) | Rig Utilization(1) | | | | | | | | Rig Utilization(1) | | | | | | | |
| Floaters | Floaters | 22 | % | | 25 | % | | 26 | % | | 32 | % | Floaters | 25 | % | | 28 | % | | | 29 | % | |
| Jackups | Jackups | 54 | % | | 54 | % | | 53 | % | | 60 | % | Jackups | 63 | % | | 55 | % | | | 50 | % | |
Other (2) | Other (2) | 100 | % | | 100 | % | | 100 | % | | 100 | % | Other (2) | 100 | % | | 100 | % | | | 100 | % | |
| Total Valaris | Total Valaris | 54 | % | | 52 | % | | 54 | % | | 57 | % | Total Valaris | 57 | % | | 54 | % | | | 54 | % | |
| ARO | ARO | 89 | % | | 97 | % | | 89 | % | | 93 | % | ARO | 91 | % | | 84 | % | | | 90 | % | |
Average Day Rates(3) | Average Day Rates(3) | | Average Day Rates(3) | | | | |
| Floaters | Floaters | $ | 197,150 | | | $ | 172,313 | | | $ | 197,905 | | | $ | 188,107 | | Floaters | $ | 197,394 | | | $ | 188,523 | | | | $ | 198,485 | | |
| Jackups | Jackups | 98,685 | | | 86,058 | | | 97,476 | | | 83,539 | | Jackups | 88,641 | | | 90,053 | | | | 95,043 | | |
Other (2) | Other (2) | 30,633 | | | 37,368 | | | 31,137 | | | 39,855 | | Other (2) | 39,227 | | | 32,538 | | | | 31,647 | | |
| Total Valaris | Total Valaris | $ | 86,861 | | | $ | 83,912 | | | $ | 88,091 | | | $ | 90,846 | | Total Valaris | $ | 89,609 | | | $ | 89,325 | | | | $ | 88,637 | | |
| ARO | ARO | $ | 95,773 | | | $ | 103,049 | | | $ | 94,485 | | | $ | 105,843 | | ARO | $ | 95,867 | | | $ | 97,251 | | | | $ | 93,199 | | |
(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. Beginning in 2021, our method for calculating rig utilization has been updated to remove the impact of suspension periods. To the extent applicable, comparative period calculations have been 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. Beginning in 2021, our method for calculating average day rates has been updated to remove the impact of suspension periods. demobilizations.To the extent applicable, comparative period calculations have been retroactively adjusted.
Detailed explanations of our operating results, including discussions of revenues, contract drilling expense and depreciation expense by segment, are provided below.
Operating Income by Segment
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.Agreements. Floaters, Jackups and ARO are also reportable segments.
Upon emergence, we ceased allocation of our onshore support costs included within contract drilling expenses to our operating segments for purposes of measuring segment operating income (loss) and as such, those costs are included in “Reconciling Items”."Reconciling Items." We have adjusted the historical periodsperiod to conform with current period presentation. Further, generalGeneral and administrative expense and depreciationDepreciation 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 53 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information on ARO and related arrangements.information. Segment information for the current quarter, the preceding quarter and prior year quarter was as follows (in millions):
TwoThree Months Ended June 30, 2021March 31, 2022 (Successor)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | $ | 49.7 | | | $ | 128.5 | | | $ | 84.0 | | | $ | 24.6 | | | $ | (84.0) | | | $ | 202.8 | |
| Operating expenses | | | | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 45.2 | | | 95.5 | | | 62.9 | | | 9.2 | | | (44.1) | | | 168.7 | |
| | | | | | | | | | | |
| Depreciation | 7.9 | | | 7.8 | | | 9.7 | | | .8 | | | (9.6) | | | 16.6 | |
| General and administrative | — | | | — | | | 3.1 | | | — | | | 9.6 | | | 12.7 | |
| | | | | | | | | | | |
| Equity in earnings of ARO | — | | | — | | | — | | | — | | | 4.8 | | | 4.8 | |
| Operating income (loss) | $ | (3.4) | | | $ | 25.2 | | | $ | 8.3 | | | $ | 14.6 | | | $ | (35.1) | | | $ | 9.6 | |
One Month Ended April 30, 2021 (Predecessor)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | $ | 18.4 | | | $ | 59.8 | | | $ | 40.8 | | | $ | 12.1 | | | $ | (40.8) | | | $ | 90.3 | |
| Operating expenses | | | | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 21.7 | | | 48.8 | | | 29.8 | | | 4.7 | | | (19.4) | | | 85.6 | |
| | | | | | | | | | | |
| Depreciation | 15.9 | | | 17.3 | | | 4.9 | | | 3.5 | | | (4.1) | | | 37.5 | |
| General and administrative | — | | | — | | | 1.2 | | | — | | | 5.2 | | | 6.4 | |
| Equity in earnings of ARO | — | | | — | | | — | | | — | | | 1.2 | | | 1.2 | |
| Operating income (loss) | $ | (19.2) | | | $ | (6.3) | | | $ | 4.9 | | | $ | 3.9 | | | $ | (21.3) | | | $ | (38.0) | |
Four Months Ended April 30, 2021 (Predecessor)
| | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | Revenues | $ | 115.7 | | | $ | 232.4 | | | $ | 163.5 | | | $ | 49.3 | | | $ | (163.5) | | | $ | 397.4 | | Revenues | $ | 99.7 | | | $ | 180.7 | | | $ | 111.3 | | | $ | 38.0 | | | $ | (111.3) | | | $ | 318.4 | |
| Operating expenses | Operating expenses | | Operating expenses | |
| Contract drilling (exclusive of depreciation) | Contract drilling (exclusive of depreciation) | 106.0 | | | 169.3 | | | 116.1 | | | 19.8 | | | (73.4) | | | 337.8 | | Contract drilling (exclusive of depreciation) | 147.6 | | | 139.2 | | | 84.2 | | | 15.5 | | | (55.2) | | | 331.3 | |
| Loss on impairment | 756.5 | | | — | | | — | | | — | | | — | | | 756.5 | | |
| | Depreciation | Depreciation | 72.1 | | | 69.7 | | | 21.0 | | | 14.8 | | | (18.0) | | | 159.6 | | Depreciation | 12.2 | | | 9.1 | | | 16.5 | | | 0.9 | | | (16.2) | | | 22.5 | |
| General and administrative | General and administrative | — | | | — | | | 4.2 | | | — | | | 26.5 | | | 30.7 | | General and administrative | — | | | — | | | 5.2 | | | — | | | 13.6 | | | 18.8 | |
| | Equity in earnings of ARO | Equity in earnings of ARO | — | | | — | | | — | | | — | | | 3.1 | | | 3.1 | | Equity in earnings of ARO | — | | | — | | | — | | | — | | | 4.3 | | | 4.3 | |
| Operating income (loss) | Operating income (loss) | $ | (818.9) | | | $ | (6.6) | | | $ | 22.2 | | | $ | 14.7 | | | $ | (95.5) | | | $ | (884.1) | | Operating income (loss) | $ | (60.1) | | | $ | 32.4 | | | $ | 5.4 | | | $ | 21.6 | | | $ | (49.2) | | | $ | (49.9) | |
Three Months Ended June 30, 2020 (Predecessor)December 31, 2021 (Successor)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | $ | 163.6 | | | $ | 186.3 | | | $ | 146.0 | | | $ | 38.9 | | | $ | (146.0) | | | $ | 388.8 | |
| Operating expenses | | | | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 150.5 | | | 163.5 | | | 112.5 | | | 15.3 | | | (71.1) | | | 370.7 | |
| Loss on impairment | 831.9 | | | .4 | | | — | | | 5.7 | | | — | | | 838.0 | |
| Depreciation | 62.0 | | | 52.8 | | | 13.3 | | | 11.2 | | | (7.8) | | | 131.5 | |
| General and administrative | — | | | — | | | 7.1 | | | — | | | 55.5 | | | 62.6 | |
| Equity in losses of ARO | — | | | — | | | — | | | — | | | (5.2) | | | (5.2) | |
| Operating income (loss) | $ | (880.8) | | | $ | (30.4) | | | $ | 13.1 | | | $ | 6.7 | | | $ | (127.8) | | | $ | (1,019.2) | |
Six Months Ended June 30, 2020 (Predecessor)
| | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | Revenues | $ | 343.2 | | | $ | 399.1 | | | $ | 286.3 | | | $ | 103.1 | | | $ | (286.3) | | | $ | 845.4 | | Revenues | $ | 100.5 | | | $ | 172.3 | | | $ | 105.4 | | | $ | 32.7 | | | $ | (105.4) | | | $ | 305.5 | |
| Operating expenses | Operating expenses | | Operating expenses | |
| Contract drilling (exclusive of depreciation) | Contract drilling (exclusive of depreciation) | 339.3 | | | 370.1 | | | 220.8 | | | 49.4 | | | (132.9) | | | 846.7 | | Contract drilling (exclusive of depreciation) | 113.8 | | | 128.0 | | | 88.9 | | | 15.4 | | | (60.6) | | | 285.5 | |
| Loss on impairment | 3,386.2 | | | 254.3 | | | — | | | 5.7 | | | — | | | 3,646.2 | | |
| | Depreciation | Depreciation | 151.4 | | | 111.3 | | | 26.3 | | | 22.3 | | | (15.3) | | | 296.0 | | Depreciation | 11.7 | | | 12.1 | | | 17.7 | | | 1.1 | | | (17.5) | | | 25.1 | |
| General and administrative | General and administrative | — | | | — | | | 15.4 | | | — | | | 100.6 | | | 116.0 | | General and administrative | — | | | — | | | 5.1 | | | — | | | 13.2 | | | 18.3 | |
| | Equity in losses of ARO | Equity in losses of ARO | — | | | — | | | — | | | — | | | (11.5) | | | (11.5) | | Equity in losses of ARO | — | | | — | | | — | | | — | | | (1.3) | | | (1.3) | |
| Operating income (loss) | Operating income (loss) | $ | (3,533.7) | | | $ | (336.6) | | | $ | 23.8 | | | $ | 25.7 | | | $ | (250.2) | | | $ | (4,071.0) | | Operating income (loss) | $ | (25.0) | | | $ | 32.2 | | | $ | (6.3) | | | $ | 16.2 | | | $ | (41.8) | | | $ | (24.7) | |
Combined Three Months Ended June 30,March 31, 2021 (Non-GAAP)(Predecessor)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | $ | 68.1 | | | $ | 188.3 | | | $ | 124.8 | | | $ | 36.7 | | | $ | (124.8) | | | $ | 293.1 | |
| Operating expenses | | | | | | | | | | | |
| Contract drilling (exclusive of depreciation) | 66.9 | | | 144.3 | | | 92.7 | | | 13.9 | | | (63.5) | | | 254.3 | |
| | | | | | | | | | | |
| Depreciation | 23.8 | | | 25.1 | | | 14.6 | | | 4.3 | | | (13.7) | | | 54.1 | |
| General and administrative | — | | | — | | | 4.3 | | | — | | | 14.8 | | | 19.1 | |
| Equity in losses of ARO | — | | | — | | | — | | | — | | | 6.0 | | | 6.0 | |
| Operating income (loss) | $ | (22.6) | | | $ | 18.9 | | | $ | 13.2 | | | $ | 18.5 | | | $ | (56.4) | | | $ | (28.4) | |
Combined Six Month Ended June 30, 2021 (Non-GAAP)
| | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total | | Floaters | | Jackups | | ARO | | Other | | Reconciling Items | | Consolidated Total |
| Revenues | Revenues | $ | 165.4 | | | $ | 360.9 | | | $ | 247.5 | | | $ | 73.9 | | | $ | (247.5) | | | $ | 600.2 | | Revenues | $ | 97.3 | | | $ | 172.6 | | | $ | 122.7 | | | $ | 37.2 | | | $ | (122.7) | | | $ | 307.1 | |
| Operating expenses | Operating expenses | | Operating expenses | |
| Contract drilling (exclusive of depreciation) | Contract drilling (exclusive of depreciation) | 151.2 | | | 264.8 | | | 179.0 | | | 29.0 | | | (117.5) | | | 506.5 | | Contract drilling (exclusive of depreciation) | 85.1 | | | 121.3 | | | 86.3 | | | 15.3 | | | (54.4) | | | 253.6 | |
| Loss on impairment | Loss on impairment | 756.5 | | | — | | | — | | | — | | | — | | | 756.5 | | Loss on impairment | 756.5 | | | — | | | — | | | — | | | — | | | 756.5 | |
| Depreciation | Depreciation | 80.0 | | | 77.5 | | | 30.7 | | | 15.6 | | | (27.6) | | | 176.2 | | Depreciation | 56.2 | | | 52.4 | | | 16.1 | | | 11.3 | | | (13.9) | | | 122.1 | |
| General and administrative | General and administrative | — | | | — | | | 7.3 | | | — | | | 36.1 | | | 43.4 | | General and administrative | — | | | — | | | 3.0 | | | — | | | 21.3 | | | 24.3 | |
| Equity in losses of ARO | — | | | — | | | — | | | — | | | 7.9 | | | 7.9 | | |
| | Equity in earnings of ARO | | Equity in earnings of ARO | — | | | — | | | — | | | — | | | 1.9 | | | 1.9 | |
| Operating income (loss) | Operating income (loss) | $ | (822.3) | | | $ | 18.6 | | | $ | 30.5 | | | $ | 29.3 | | | $ | (130.6) | | | $ | (874.5) | | Operating income (loss) | $ | (800.5) | | | $ | (1.1) | | | $ | 17.3 | | | $ | 10.6 | | | $ | (73.8) | | | $ | (847.5) | |
Floaters
Floater revenue decreased $95.5$0.8 million, or 58%1%, for the combined Successorcurrent quarter as compared to the preceding quarter, primarily due to $9.3 million from a decline in operating days partially offset by $5.5 million from an increase in customer reimbursable revenue and Predecessor results$2.1 million from higher average day rates.
Floater revenue increased $2.4 million, or 2%, for the three months ended June 30, 2021,current quarter as compared to the prior year quarter, primarily due to $58.7$9.1 million as a result of fewer days under contract across the floater fleet and $46.3 million due to termination fees received for certain rigs in the prior year period. This decline wasfrom increased customer reimbursable revenue, partially offset by a $13.8 million increasedecrease in certain deferred revenue for certain rigs with higheramortization as well as slightly lower average day rates for the combined three months ended June 30, 2021 as compared to the prior year quarter.
Floater revenue decreased $177.8 million, or 52%, for the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period primarily due to $146.5 million as a result of fewer days under contract across the floater fleet, $46.3 million due to termination fees received for certain rigs in prior year period, and $13.5 million from the sale of VALARIS 5004, which operated in the prior year period. This decline was partially offset by a $28.4 million increase in revenue for certain rigs with higher average day rates for the combined six months ended June 30, 2021 as compared to the prior year period.operating days.
Floater contract drilling expense decreased $83.6increased $33.8 million, or 56%30%, for the combined Successorcurrent quarter as compared to the preceding quarter, primarily due to an increase in rig reactivation costs of $26.9 million and Predecessor resultshigher personnel costs of $5.4 million.
Floater contract drilling expense increased $62.5 million, or 73%, for the three months ended June 30, 2021,current quarter as compared to the prior year quarter, primarily due to $70.8an increase of $55.1 million in reactivation costs, a $7.7 million increase in reimbursable costs and a $3.9 million increase in personnel costs, partially offset by $10.5 million of lower costcosts on idle rigs, $10.4 million due to the sale of VALARIS 5004, VALARIS 5006, VALARIS 8500, VALARIS 8501, VALARIS 8502, VALARIS 8504, VALARIS DS-3, VALARIS DS-5 and VALARIS DS-6.
Floater contract drilling expense decreased $188.1 million, or 55%, for the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period primarily due to $133.8 million as a result of fewer days under contract across the floater fleet, $23.1 million to the sale of VALARIS 5004, VALARIS 5006, VALARIS 8500, VALARIS 8501, VALARIS 8502, VALARIS 8504, VALARIS DS-3, VALARIS DS-5 and VALARIS DS-6, as well as reduced costs resulting primarily from spend control efforts.rigs.
During the secondprior year quarter, of 2020, we recorded non-cash losses on impairment totaling $831.9$756.5 million, with respect to certain assets in our Floater segment. See "Note 75 - Property and Equipment" for additional information.
During the four months ending April 30, 2021 and the six months ended June 30, 2020, the Predecessor recorded non-cash losses on impairment totaling $756.5 million and $3.4 billion, respectively, with respect to certain assetsour condensed consolidated financial statements included in our Floater segment. See "Note 7 - Property and Equipment""Item 1. Financial Statements" for additional information.
Floater depreciation expense decreased $44.0 million, or 78%, for the combined Successor and Predecessor results for the three months ended June 30, 2021,current quarter as compared to the prior year quarter, primarily due to the reduction in values of property and equipment from the application of fresh start accounting.
Floater depreciation expense decreased foraccounting on the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period, primarily due to the reduction in values of property and equipment from the application of fresh start accounting and 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.Effective Date.
Jackups
Jackup revenues increased $2.0$8.4 million, or 1%5%, for the combined Successor and Predecessor resultscurrent quarter as compared to the preceding quarter, primarily due to $5.9 million from an increase in operating days.
Jackup revenues increased $8.1 million, or 5%, for the three months ended June 30, 2021,current quarter as compared to the prior year quarter, primarily due to $19.9 million from increased operating days and $3.6 million from increased customer reimbursable revenue. This increase was partially offset by a decline of $15.4 million due to lower average day rates.
Jackup contract drilling expense increased $11.2 million, or 9%, for the current quarter as compared to the preceding quarter, primarily due to adjustments of certain accruals in the preceding quarter of $4.8 million as well as an increase of $4.0 million in mobilization costs.
Jackup contract drilling expense increased $17.9 million, or 15%, for the current quarter as compared to the prior year quarter, primarily due to a $19.7$7.6 million increase in revenue for certain rigs with higher average day rates for the three months ended June 30, 2021 as compared to the prior year quarter. This increase was partially offset by $14.1 million due to the sale of VALARIS JU-84, VALARIS JU-87 and VALARIS JU-101 which operated in the prior year quarter, and $5.4 million asreimbursable expenses, a result of fewer days under contract across the jackup fleet.
Jackup revenues decreased $38.2 million, or 10%, for the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period, primarily due to declines of $41.6 million from fewer days under contract across the jackup fleet and $33.9 million due to the sale of VALARIS JU-84, VALARIS JU-87, VALARIS JU-88 and VALARIS JU-101 which operated in the prior year quarter. This decline was partially offset by a $30.1$5.7 million increase in revenue for certain rigs with higher average day rates in the six months ended June 30, 2021.
Jackup contract drilling expense decreased $19.2 million, or 12%, for the combined Successorscheduled repairs and Predecessor results for the three months ended June 30, 2021, as compared to the prior year quarter, primarily due to declines of $17.6 million resulting from the sale of VALARIS JU-68, VALARIS JU-70, VALARIS JU-71, VALARIS JU-84, VALARIS JU-87, VALARIS JU-88, VALARIS JU-101maintenance and VALARIS JU-105, and $13.5 million of lower cost on idle rigs. This decrease was partially offset by a $16.5$5.4 million increase in reactivation cost for certain rigs.
Jackup contract drilling expense decreased $105.3 million, or 28%, for the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period, primarily due to $59.4 million of lower cost on idle rigs, $29.4 million due to the sale of VALARIS JU-68, VALARIS JU-70, VALARIS JU-71, VALARIS JU-84, VALARIS JU-87, VALARIS JU-88, VALARIS JU-101 and VALARIS JU-105, and reduced costs resulting largely from spend control efforts. This decrease was partially offset by a $16.5 million increase in reactivation cost for certain rigs.
During the three and six months ended June 30, 2020, we recorded a non-cash loss on impairment of $0.4 million and $254.3 million, respectively, with respect to certain assets in our Jackup segment. See "Note 7 - Property and Equipment" for additional information.personnel costs.
Jackup depreciation expense decreased $27.7$43.3 million, or 52%83%, for the combined Successor and Predecessor results for the three months ended June 30, 2021current quarter as compared to the prior year quarter, primarily due to the reduction in values of property and equipment from the application of fresh start accounting.
Jackup depreciation expense decreased primarily $33.8 million, or 30%, foraccounting on the combined Successor and Predecessor results for the six months ended June 30, 2021 primarily due to the reduction in values of property and equipment from the application of fresh start accounting and lower depreciation expense on certain non-core assets which were impaired in the second quarter of 2020, some of which were subsequently sold in 2020.Effective Date.
ARO
The operating revenues of ARO reflect revenues earned under drilling contracts with Saudi Aramco for both 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 the seconded employees' services related. General and administrative expenses include costs incurred under the Transition Services Agreement and other administrative costs. Services under the Transition Services Agreement were completed by December 31, 2020.
ARO revenue decreased $21.2 million or 15%, and $38.8 million or 14%, for three and six months ended June 30, 2021, respectively, as compared to the prior year period 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 decreased $19.8 million or 18%, and $41.8 million or 19%, for three and six months ended June 30, 2021, respectively, as compared to the prior year period primarily due to lower costs for repairs and maintenance of $7.8 million and $23.1 million, respectively, as well as a reduction in bareboat charter expense for the rigs leased from us for the respective periods.
ARO depreciation expense increased $1.3 million or 10%, and $4.4 million or 17% for three and six months ended June 30, 2021, respectively, as compared to the prior year period primarily due to capital expenditures.
ARO general and administrative expenses decreased $2.8 million or 39% and $8.1 million or 53%, for the three and six months ended June 30, 2021, respectively, as compared to the prior year period primarily 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 5 3 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information on ARO.
OtherARO revenue increased $5.9 million, or 6%, for the current quarter as compared to the preceding quarter, primarily due to $6.8 million incremental revenues from more operating days on certain rigs which were undergoing maintenance in the preceding quarter.
Other revenuesARO revenue decreased $2.2$11.4 million, or 9%, for the combined Successor and Predecessor results for the three months ended June 30, 2021,current quarter as compared to the prior year quarter, primarily due to $4.5fewer operating days related to two rigs which operated in the prior year quarter but completed their contracts in 2021.
ARO contract drilling expense decreased $4.7 million, or 5%, for the current quarter as compared to the preceding quarter, due to a $5.2 million reduction in repairs and maintenance costs as certain rigs were undergoing maintenance projects in the preceding quarter.
Other
Other revenues increased $5.3 million, or 16%, for the current quarter as compared to the preceding quarter, primarily due to $2.6 million from higher average day rates on certain rigs and $3.2 million of lowerhigher revenues earned under the Lease Agreements with ARO. See "Note 53 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information.
Other revenues decreased $29.2 million for the combined Successor and Predecessor results for the six months ended June 30, 2021, as compared to the prior year period, primarily due to $20.5 million and $9.4 million of lower revenues earned under the Secondment and Lease Agreements with ARO, respectively. See "Note 5 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information.
Other contract drilling expensesdepreciation expense decreased $1.4$10.4 million, and $20.4 millionor 92%, for the combined Successor and Predecessor results for the three and six months ended June 30, 2021, respectively,current quarter as compared to the prior year period,quarter, primarily due to $1.1 millionthe reduction in values of property and $18.6 million decrease in cost for services provided to ARO underequipment from the Secondment Agreement forapplication of fresh start accounting on the respective periods as almost all remaining employees seconded to ARO became employees of ARO during the second quarter of 2020.Effective Date.
Other Income (Expense)
The following table summarizes other income (expense) (in millions):
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | Combined (Non-GAAP) | | Predecessor | | | |
| Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | | Three Months Ended June 30, 2021 | | Three Months Ended June 30, 2020 | |
| Interest income | $ | 7.8 | | | | $ | 1.0 | | | $ | 8.8 | | | $ | 5.7 | | | | |
| Interest expense, net: | | | | | | | | | | | |
| Interest expense | (8.0) | | | | (1.1) | | | (9.1) | | | (116.8) | | | | |
| Capitalized interest | — | | | | — | | | — | | | .6 | | | | |
| | (8.0) | | | | (1.1) | | | (9.1) | | | (116.2) | | | | |
| Reorganization items, net | (4.1) | | | | (3,532.4) | | | (3,536.5) | | | — | | | | |
| Other, net | 5.7 | | | | (1.2) | | | 4.5 | | | 5.1 | | | | |
| | $ | 1.4 | | | | $ | (3,533.7) | | | $ | (3,532.3) | | | $ | (105.4) | | | | |
| | | Successor | | | Predecessor | | Combined (Non-GAAP) | | Predecessor | | Successor | | | Predecessor | |
| | Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Month Ended June 30, 2021 | | Six Months Ended June 30, 2020 | | Three Months Ended March 31, 2022 | | Three Months Ended December 31, 2021 | | | | Three Months Ended March 31, 2021 | |
| Interest income | Interest income | $ | 7.8 | | | | $ | 3.6 | | | $ | 11.4 | | | $ | 10.5 | | Interest income | $ | 10.9 | | | $ | 11.0 | | | | | $ | 2.6 | | |
| Interest expense, net: | | | | |
| | Interest expense | Interest expense | (8.0) | | | | (2.4) | | | (10.4) | | | (230.7) | | Interest expense | (11.5) | | | (11.7) | | | | | (1.3) | | |
| Capitalized interest | — | | | | — | | | — | | | 1.3 | | |
| | | | (8.0) | | | | (2.4) | | | (10.4) | | | (229.4) | | |
| Reorganization items, net | Reorganization items, net | (4.1) | | | | (3,584.6) | | | (3,588.7) | | | — | | Reorganization items, net | (1.0) | | | (4.9) | | | | | (52.2) | | |
| Other, net | 5.7 | | | | 19.9 | | | 25.6 | | | 5.6 | | |
| Net foreign currency exchange gains | | Net foreign currency exchange gains | 4.7 | | | 3.3 | | | | | 16.6 | | |
| Net gain on sale of property | | Net gain on sale of property | 2.5 | | | 21.0 | | | | | 1.4 | | |
| Other | | Other | 3.8 | | | 2.7 | | | | | 4.5 | | |
| | | $ | 1.4 | | | | $ | (3,563.5) | | | $ | (3,562.1) | | | $ | (213.3) | | | $ | 9.4 | | | $ | 21.4 | | | | | $ | (28.4) | | |
Interest income increased for the combined Successor and Predecessor results for the three and six months ended June 30, 2021current quarter as compared to the respective prior year periodsquarter primarily due to amortization of the discount on our note receivable from ARO. This increase was partially offset by lower LIBOR rates earned on that note.ARO recorded in fresh start accounting.
Interest expense decreasedincreased by $107.7 million and $220.3$10.2 million for the combined Successor and Predecessor results for the three and six months ended June 30, 2021, respectively,current quarter as compared to the prior year periodsquarter as current quarter interest expense is attributable to our First Lien Notes issued upon the Effective Date and in the prior year quarter we did not accrue interest on our Predecessor outstanding debt or amortize discounts, premiums and debt issuance costs subsequent to the chapterChapter 11 filing. Further, our interest costs are lower as a result of our lower debt level following emergence from chapter 11.Cases.
Reorganization items, net of $3.5 billion$4.9 million recognized during the combined Successor and Predecessor results for the three and six months ended June 30, 2021preceding quarter was related to legal and other professional advisory service fees pertainingdirectly related to the Chapter 11 Cases, contractCases.
Reorganization items,
net of $52.2 million recognized during prior year quarter was related to
rejecting certain operating leases and the effects of the emergence from bankruptcy, including the application of fresh start accounting.otherother net losses and expenses directly related to Chapter 11
Cases. See ""Note 2 - Chapter 11 Proceedings"Cases, consisting of legal and other professional advisory fees of $47.8 million and contract items related to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information.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 losses of $0.1 million and gains $16.5 million were included in other, net, for the combined Successor and Predecessor results for the three and six months ended June 30, 2021, respectively. During the combined Successor and Predecessor results for the three months ended June 30, 2021, the net foreign currency exchange losses were primarily attributable to the Euro partially offset by gains in the Brazilian Reals. During the combined Successor and Predecessor results for the six months ended June 30, 2021, the net foreign currency exchange gains were primarily attributable to the Libyan Dinar and Euro.
Net foreign currency exchange losses of $1.2 million and gains of $2.6$4.7 million respectively, inclusive of offsetting fair value derivatives, were included in other, net, for the three and six months ended June 30, 2020 (Predecessor), respectively. During the three months ended June 30, 2020 (Predecessor), the net foreign currency exchange losses werecurrent quarter primarily attributableincluded $3.4 million related to the Euro and the neteuros. Net foreign currency exchange gains of $3.3 million for the six months ended June 30, 2020 (Predecessor), werepreceding quarter primarily attributableincluded $2.7 million related to euros. Net foreign currency exchange gains of $16.6 million for the prior year quarter primarily included $11.8 million and $4.3 million related to Libyan dinars and euros, respectively.
Net gains on the sale of property decreased by $18.5 million for the current quarter as compared to the Euro and Australian dollar.preceding quarter primarily due to a decrease in gains from rigs sold.
Provision for Income Taxes
Valaris Limited the Successor Company and our parent company, is domiciled and resident in Bermuda. 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-Bermuda subsidiaries is not subject to Bermuda taxation as there is not an income tax regime in Bermuda.
Legacy Valaris plc, the Predecessor Company and our former parent company was domiciled and resident in the U.K. The income of our non-U.K. subsidiaries was generally not subject to U.K. taxation.
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 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.
Our drilling rigs frequently move from one taxing jurisdiction to another to perform contract drilling services. In some instances, the movement of drilling rigs among taxing jurisdictions will involve the transfer of ownership of the drilling rigs among our subsidiaries. As a result of frequent changes in the taxing jurisdictions in which our drilling rigs are operated and/or owned, changes in profitability levels and changes in tax laws, our annual effective income tax rate may vary substantially from one reporting period to another.
Discrete income tax expensebenefit for the two months ended June 30, 2021 (Successor)current quarter was $5.6$14.5 million and was primarily attributable to changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and resolution of other prior period tax matters.years. Discrete income tax benefit for the one-month ended April 30, 2021 (Predecessor)preceding quarter was $18.1$29.5 million and was primarily attributablerelated to fresh start accounting adjustments.a reduction in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and deferred tax benefits associated with Swiss tax reform. Discrete income tax expense for the four months ended April 30, 2021 (Predecessor)prior year quarter was $2.2$20.3 million and was primarily attributable to changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and resolution of other prior period tax matters offset by discrete tax benefit related to fresh start accounting adjustments.years. Excluding the aforementioned discrete tax items, income tax expense was $13.8 million for the two months ended June 30, 2021 (Successor), one monthcurrent quarter, income tax benefit was $1.5 million for the preceding quarter and four months ended April 30, 2021 (Predecessor)income tax expense was $9.5$11.4 million $2.6for the prior year quarter. The $15.3 million increase in income tax expense as compared to the preceding quarter was primarily due to the derecognition of valuation allowance against deferred tax assets in the preceding quarter resulting from a change in estimate of future taxable income and $14.0 million, respectively.to changes in the relative components of our earnings and losses generated in tax jurisdictions with higher effective tax rates in the current quarter as compared to the preceding quarter.
Discrete income tax benefit for the three months ended June 30, 2020 (Predecessor) was $47.3 million and was primarily attributable to rig impairments and other resolutions of prior year tax matters. Discrete income tax benefit for the six months ended June 30, 2020 (Predecessor) was $211.7 million and was primarily attributable to a restructuring transaction, rig impairments, implementation of the U.S. Cares Act, changes in liabilities for unrecognized tax benefits associated with tax positions taken in prior years and resolution of other prior period tax matters. Excluding the aforementioned discrete tax items, income tax expense for the three and six months ended June 30, 2020 (Predecessor) was $31.5 million and $43.9 million, respectively.
LIQUIDITY AND CAPITAL RESOURCES
First Lien NotesLiquidity
The First Lien Notes were issued pursuantWe expect to fund our short-term liquidity needs, including contractual obligations and anticipated capital expenditures as well as working capital requirements, from cash and cash equivalents, proceeds from the Indenture dated April 30, 2021 (the "First Lien Notes Indenture"), among Valaris, certain directsale of assets and indirect subsidiariescash flows from operations. We expect to fund our long-term liquidity needs, including contractual obligations and anticipated capital expenditures from cash and cash equivalents, cash flows from operations, as well as cash to be received from maturity of Valaris as guarantors,our long-term notes receivable and Wilmington Savings Fund Society, FSB, as collateral agent and trustee (in such capacities,from the “Collateral Agent”).
On the Effective Date, in accordance with the plandistribution of reorganization and Backstop Commitment Agreement, dated August 18, 2020 (as amended, the "BCA"), the Company consummated the rights offering of senior secured first lien notes (“First Lien Notes”) and associated shares in an aggregate principal amount of $550 million, In accordance with the BCA, certain holders of senior notes claims and certain holders of claims under the Revolving Credit Facility ("Backstop Parties") who provided backstop commitments received the backstop premium.
The First Lien Notes are guaranteed, jointly and severally, on a senior basis, by certain of the direct and indirect subsidiaries of the Company under the First Lien Notes Indenture. The First Lien Notes and such guarantees are secured by first-priority perfected liens on 100% of the equity interests of each Restricted Subsidiary directly owned by the Company or any guarantor and a first-priority perfected lien on substantially all assets of the Company and each guarantor of the First Lien Notes, in each case subject to certain exceptions and limitations. The following is a brief description of the material provisions of the First Lien Notes Indenture and the First Lien Notes.
The First Lien Notes are scheduled to mature on April 30, 2028. Interestearnings from ARO. If necessary, we may rely on the First Lien Notes accrues, at Valaris’s option, at a rate of: (i) 8.25% per annum, payable in cash; (ii) 10.25% per annum, with 50%issuance of such interest to be payable in cash and 50% of such interest to be paid in kind; debt and/or (iii) 12% per annum, with the entirety of such interest to be paid in kind. The Company shall pay interest semi-annually in arrears on May 1 and November 1 of each year, commencing November 1, 2021. Interest on the First Lien Notes shall accrue from the most recent date to which interest has been paid or, if no interest has been paid, from April 30, 2021. Interest shall be computed on the basis of a 360-day year of twelve 30-day months.
At any time prior to April 30, 2023, the Company may redeem up to 35% of the aggregate principal amount of the First Lien Notes at a redemption price of 104% up to the net cash proceeds received by the Company from equity offerings provided that at least 65% of the aggregate principal amount of the First Lien Notes remains outstanding and provided that the redemption occurs within 120 days after such equity offering of the Company. At any time prior to April 30, 2023 the Company may redeem the First Lien Notes at a redemption price of 104% plus a “make-whole” premium. On or after April 30, 2023, the Company may redeem all or part of the First Lien Notes at fixed redemption prices (expressed as percentages of the principal amount), plus accrued and unpaid interest, if any, to, but excluding, the redemption date. The Company may also redeem the First Lien Notes, in whole or in part, at any time and from time to time on or after April 30, 2026 at a redemption price equal to 100% of the principal amount plus accrued and unpaid interest, if any, to, but excluding, the applicable redemption date. Notwithstanding the foregoing, if a Change of Control (as definedsecurities in the First Lien Notes Indenture, with certain exclusions as provided therein) occurs,future to supplement our liquidity needs. However, the Company will be required to make an offer to repurchase all or any part of each note holder’s notes at a purchase price equal to 101% of the aggregate principal amount of First Lien Notes repurchased, plus accrued and unpaid interest to, but excluding, the applicable date.
The First Lien Notes Indenture contains covenants that limit among other things, Valaris’sour ability and the ability of the guarantors and other restricted subsidiaries, to: (i)to incur assume or guarantee additional indebtedness; (ii) pay dividends or distributions on Equity Interests (as defined in the First Lien Notes Indenture) or redeem or repurchase Equity Interests; (iii) make investments; (iv) repay or redeem junior debt; (v) transfer or sell assets; (vi) enter into sale and lease back transactions; (vii) create, incur or assume liens; and (viii) enter into transactions with certain affiliates. These covenants are subject to a number of important limitations and exceptions.
The First Lien Notes Indenture also provides for certain customary events of default, including, among other things, nonpayment of principal or interest, breach of covenants, failure to pay final judgments in excess of a specified threshold, failure of a guarantee to remain in effect, failure of a collateral document to create an effective security interest in collateral, with a fair market value in excess of a specified threshold, bankruptcy and insolvency events, cross payment default and cross acceleration, which could permit the principal, premium, if any, interest and other monetary obligations on all the then outstanding First Lien Notes to be declared due and payable immediately.
Liquidity
Our liquidity position is summarized in the table below (in millions, except ratios):
| | | | | | | | | | | | | | | | | |
| | Successor | | | Predecessor |
| | June 30,
2021 | | | December 31,
2020 |
| | | |
| Cash and cash equivalents | | $ | 608.8 | | | | $ | 325.8 | |
Available DIP Facility capacity(1) | | — | | | | 500.0 | |
| | | | | |
| Total liquidity | | $ | 608.8 | | | | $ | 825.8 | |
| Working capital | | $ | 821.1 | | | | $ | 746.1 | |
Current ratio(2) | | 3.1 | | | | 2.7 | |
(1)The DIP Facility was terminated upon our emergence from the Chapter 11 Cases on the Effective Date.
(2)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 notesOur Cash and Revolving Credit Facility, and rig holding costs for VALARIS DS-13 and VALARIS DS-14 to “Liabilities Subject to Compromise”cash equivalents as of March 31, 2022 and December 31, 2020.
Cash2021 were $578.2 million and Debt
As discussed in$608.7 million and we have no debt principal payments due until 2028. See "Note 28 - Chapter 11 Proceedings" and above, we filed the Chapter 11 CasesDebt" to effect a comprehensive restructuring of our indebtedness. As of June 30, 2021, our only outstanding long-term debt consisted ofcondensed consolidated financial statements included in "Item 1. Financial Statements" for additional information on the First Lien Notes.
Cash Flow and Capital Expenditures
Absent periods where we have significant financing or investing transactions or activities, such as debt or equity issuances, debt repayments, business combinations or asset sales, our primary sources and uses of cash are driven by cash generated from or used in operations and capital expenditures. Our net cash provided by or used in operating activities and capital expenditures were as follows (in millions):
| | | | | | | | | | | | | | | | |
| Successor | | | | | Predecessor |
| Three Months Ended March 31, 2022 | | | | | Three Months Ended March 31, 2021 |
| Net cash provided by (used in) operating activities | $ | 0.5 | | | | | | $ | (31.7) | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Capital expenditures | 38.5 | | | | | | 6.0 | |
During the twothree months ended June 30, 2021,March 31, 2022 (Successor), we generated $0.5 million from operating activities and our primary uses of cash were $25.9$38.5 million for the enhancement and other improvements of our drilling rigs. During the three months ended March 31, 2021 (Predecessor), our primary uses of cash were $31.7 million used in operating activities and $8.1$6.0 million for the enhancement and other improvements of our drilling rigs.
During the fourthree months ended April 30, 2021, our primary sourcesMarch 31, 2022 (Successor), net cash provided by operating activities was $0.5 million primarily related to higher net collections of customer receivables partially offset by cash were $520.0 millionoutflows from the issuancepayment of the First Lien Notes and proceeds of $30.1 million for the disposition of assets. Our primary uses of cash for the same period were $39.8 million used in operating activities and $8.7 million for the enhancement and other improvements of our drilling rigs.certain taxes.
During the sixthree months ended June 30, 2020, our primary source of cash was $551.0 million inMarch 31, 2021 (Predecessor), net borrowings under our Revolving Credit Facility. Our primary uses of cash for the same period were $381.1 million used in operating activities, $67.1 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 were as follows (in millions):
| | | | | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor | | Predecessor |
| Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | | Six Months Ended June 30, 2020 |
| Net cash used in operating activities | $ | (25.9) | | | | $ | (39.8) | | | $ | (381.1) | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | |
| Capital expenditures | 8.1 | | | | 8.7 | | 67.1 | |
Net cash used in operating activities was $25.9$31.7 million primarily related to contributions to pension and $39.8 million during the two months ended June 30, 2021 and four months ended April 30, 2021, respectively. The cash outflow for the Successor primarily relates to reorganization costs while the cash outflow for the Predecessor primarily relates to declining marginsother post-retirement benefit plans and reorganization costs.
Prior to our chapter 11 filing, we had contractual commitments for theWe have construction of VALARIS DS-13 and VALARIS DS-14 (the "Newbuild Rigs"). On February 26, 2021, we entered intoagreements, as amended, agreements with thea Shipyard that became 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 VALARIS DS-13 and VALARIS DS-14 rigs under construction on or before December 31, 2023. Under the amended agreements, the purchase priceprices 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 removed any Company guarantee.
FinancingWe continue to take a disciplined approach to reactivations with our stacked rigs, only returning them to the active fleet when there is visibility into work at attractive economics. In most cases, we expect the initial contract to pay for the reactivation costs and that the rig would have solid prospects for longer-term work. Most of this reactivation cost will be operating expenses, recognized in the income statement, related to de-preservation activities, including reinstalling key pieces of equipment and crewing up the rigs. Capital Resourcesexpenditures during reactivations include rig modifications, equipment overhauls and any customer required capital upgrades. We would generally expect to be compensated for these customer-specific enhancements.
Successor First Lien NotesBased on our current projections, we expect capital expenditures during 2022 to approximate $225 to $250 million for rig enhancement, reactivation and upgrade projects. We expect that customers will reimburse us for a significant portion of the 2022 expenditures. 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.
On the Effective Date, pursuant to the Backstop Commitment Agreement and in accordance with the plan of reorganization, the Company consummated the Rights Offering of First Lien Notes and associated shares in an aggregate principal amount of $550.0 million. The First Lien Notes are scheduled to mature on April 30, 2028.
InterestApproximately $70 million of our expected capital expenditures for 2022 relate to the reactivation and upgrade of the VALARIS DS-11 for an eight-well contract for a deepwater project in the U.S. Gulf of Mexico expected to commence in mid-2024. The contract requires the rig to be upgraded with 20,000 psi well-control equipment. In February 2022, the customer decided not to sanction and therefore withdrew from the project associated with this contract. In March 2022, the contract was novated to another customer, which was a partner on the First Lien Notes accrues, at Valaris’s option, at a rate of: (i) 8.25% per annum, payableproject. No material changes to the contract resulted from the novation, including with respect to the termination provisions in cash; (ii) 10.25% per annum, with 50%the event the project does not receive final investment decision (FID). In the event of such interesttermination, the early termination fee and contractual reimbursements from the customer will be more than sufficient to be payable in cashcover expenses and 50% of such interest to be paid in kind; or (iii) 12% per annum, withcommitments incurred by Valaris on the entirety of such interest to be paid in kind.project.
PredecessorSenior Notes
The commencement ofAs we reactivate rigs, we expect spending levels to increase beyond the Chapter 11 Cases resultedlevels we incurred in an event of default under each series2021, with more spending associated with reactivation of our senior notes and all obligations thereunder were accelerated. However, any efforts to enforce payment obligations related to the acceleration of our debt were automatically stayed as a result of the filing of the Chapter 11 Cases. 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 were classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of December 31, 2020. On the Effective Date, pursuant to the plan of reorganization, each series of our senior notes were cancelled and the holders thereunder received the treatment as set forth in the plan of reorganization.
In December 2016, Ensco Jersey Finance Limited, a wholly-owned subsidiary of Valaris plc, issued $849.5 million aggregate principal amount of the 2024 Convertible Notes in a private offering. The 2024 Convertible Notes were fully and unconditionally guaranteed, on a senior, unsecured basis, by Valaris plc. Under the terms of our debt agreement, we had 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, were automatically stayed as a result of the filing of the Chapter 11 Cases. Accordingly, the aggregate principal amount of 2024 Convertible Notes outstanding as well as associated accrued interest as of the Petition Date were classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of December 31, 2020. On the Effective Date, pursuant to the plan of reorganization, all outstanding obligations under the senior notes, including the 2024 Convertible Notes, were cancelled and the holders thereunder received the treatment as set forth in the plan of reorganization.
PredecessorRevolving Credit Facility
The commencement of the Chapter 11 Cases resulted in an event of default under our Revolving Credit Facility. However, the ability of the lenders to exercise remedies in respect of the Revolving Credit Facility was stayed upon commencement of the Chapter 11 Cases. Accordingly, the $581.0 million of outstanding borrowing as well as accrued interest as of the Petition Date were classified as Liabilities Subject to Compromise in our Condensed Consolidated Balance Sheets as of December 31, 2020. On the Effective Date, pursuant to the plan of reorganization, the Revolving Credit Facility was cancelled and the holders thereunder received the treatment as set forth in the plan of reorganization.
Prior to the Effective Date, pursuant to the plan of reorganization, all undrawn letters of credit issued under the Revolving Credit Facility were collateralized pursuant to the terms of the Revolving Credit Facility. As of June 30, 2021, we had $22.0 million of collateralized letters of credit issued to lenders of the predecessor Revolving Credit Facility.
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 5 - Equity Method Investment in ARO"floater fleet relative to our condensed consolidated financial statements included in "Item 1. Financial Statements"jackup fleet and for additional information on our investment in ARO and notes receivable from ARO.
The following table summarizes the maturity schedulerigs that have been preservation stacked for longer periods of our notes receivable from ARO as of June 30, 2021 (in millions):
| | | | | |
Maturity Date | Principal Amount |
October 2027 | $ | 265.0 | |
October 2028 | 177.7 | |
| |
Total | $ | 442.7 | |
Other Commitments
We have other commitments that we are contractually obligated to fulfill with cash under certain circumstances. As of June 30, 2021, we were contingently liable for an aggregate amount of $114.4 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 June 30, 2021, we had collateral deposits in the amount of $37.4 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. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, on a proportionate basis. See "Note 5 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information on our joint venture with ARO.time.
We review from time to time possible acquisition opportunities relating to our business, which may include the acquisition of rigs or other businesses. The timing, size or success of any acquisition efforts and the associated potential capital commitments are unpredictable and uncertain. We may seek to fund all or part of any such efforts with cash on hand and proceeds from debt and/or equity issuances and may issue equity directly to the sellers. Our ability to obtain capital for additional projects to implement our growth strategy over the longer term will depend on our future operating performance, financial condition and, more broadly, on the availability of equity and debt financing. Capital availability will be affected by prevailing conditions in our industry, the global economy, the global financial markets and other factors, many of which are beyond our control. In addition, any additional debt service requirements we take on could be based on higher interest rates and shorter maturities and could impose a significant burden on our results of operations and financial condition, and the issuance of additional equity securities could result in significant dilution to shareholders.
Recent Financing and Capital Resources
First Lien Notes
We have $550 million aggregate principal amount of Senior Secured First Lien Notes due 2028 (the "First Lien Notes") which were issued on the Effective Date pursuant to the Indenture. The First Lien Notes are scheduled to mature on April 30, 2028. See "Note 8 - Debt" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information on the First Lien Notes.
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, mature in 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 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 3 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" 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, 2022 (in millions):
| | | | | |
| Maturity Date | Principal Amount |
| October 2027 | $ | 265.0 | |
| October 2028 | 177.7 | |
| |
| Total | $ | 442.7 | |
Other Commitments
We have other commitments that we are contractually obligated to fulfill with cash under certain circumstances. As of March 31, 2022, we were contingently liable for an aggregate amount of $33.6 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, 2022, we had collateral deposits in the amount of $27.1 million with respect to these agreements.
In connection with our 50/50 unconsolidated joint venture, 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, each with a shipyard price of $176.0 million. These newbuild rigs are expected to be delivered in the first or second quarter of 2023 and ARO is expected to place orders for two additional newbuild jackups 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. ARO paid a 25% down payment from cash on hand for each of the newbuilds ordered in January 2020 and is actively exploring financing options for remaining payments due upon delivery. In the event ARO has insufficient cash from operations or is unable to obtain third-party financing, each partner may periodically be required to make additional capital contributions to ARO, up to a maximum aggregate contribution of $1.25 billion from each partner to fund the newbuild program. Each partner's commitment shall be reduced by the actual cost of each newbuild rig, as delivered, on a proportionate basis. See "Note 3 - Equity Method Investment in ARO" to our condensed consolidated financial statements included in "Item 1. Financial Statements" for additional information on ARO.
Tax Assessments
During 2019, the Australian tax authorities issued aggregate tax assessments totaling approximately A$101.0101 million (approximately $75.7$75.6 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$42.042 million payment (approximately $29 million at then-current exchange rates) to the Australian tax authorities to litigate the assessment. We have a $18.0an $18.8 million liability for unrecognized tax benefits relating to these assessments as of June 30, 2021.March 31, 2022. 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.
SUPPLEMENTAL FINANCIAL INFORMATION
Guarantees of Registered Securities
The First Lien Notes issued by Valaris Limited have been fully and unconditionally guaranteed, jointly and severally, on a senior secured basis, by certain of the direct and indirect subsidiaries (the “Guarantors”) of Valaris Limited under the First Lien Notes Indenture governing the First Lien Notes (the “Guarantees”). The First Lien Notes and Guarantees are secured by liens on the collateral, including, among other things, subject to certain agreed security principles, (i) first-priority perfected liens on 100% of the equity interests of each restricted subsidiary directly owned by Valaris Limited or any Guarantor and (ii) a first-priority perfected lien on substantially all assets of Valaris Limited and each Guarantor, in each case subject to certain exceptions and limitations (collectively, the “Collateral”). We are providing the following information about the Guarantors and the Collateral in compliance with Rules 13-01 and 13-02 of Regulation S-X.
First Lien Note Guarantees
The Guarantees are joint and several senior secured obligations of each Guarantor and rank equally in right of payment with existing and future senior indebtedness of such Guarantor and effectively senior to such Guarantor’s existing and future indebtedness (i) that is not secured by a lien on the Collateral securing the First Lien Notes, or (ii) that is secured by a lien on the Collateral securing the First Lien Notes ranking junior to the liens securing the First Lien Notes. The Guarantees rank effectively junior to such Guarantor’s existing and future secured indebtedness (i) that is secured by a lien on the Collateral that is senior or prior to the lien securing the First Lien Notes, or (ii) that is secured by liens on assets that are not part of the Collateral, to the extent of the value of such assets. The Guarantees rank equally with such Guarantor’s existing and future indebtedness that is secured by first-priority liens on the Collateral and senior in right of payment to any existing and future subordinated indebtedness of such Guarantor. The Guarantees are structurally subordinated to all existing and future indebtedness and other liabilities of any non-Guarantors, including trade payables (other than indebtedness and liabilities owed to such Guarantor).
Under the First Lien Notes Indenture, a Guarantor may be automatically and unconditionally released and relieved of its obligations under its guarantee under certain circumstances, including: (1) in connection with any sale, transfer or other disposition (including by merger, consolidation, distribution, dividend or otherwise) of all or substantially all of the assets of such Guarantor to a person that is not the Company or a restricted subsidiary, if such sale, transfer or other disposition is conducted in accordance with the applicable terms of the First Lien Notes Indenture, (2) in connection with any sale, transfer or other disposition (including by merger, consolidation, amalgamation, distribution, dividend or otherwise) of all of the capital stock of any Guarantor, if such sale, transfer or other disposition is conducted in accordance with the applicable terms of the First Lien Notes Indenture, (3) upon Valaris’sour exercise of legal defeasance, covenant defeasance or discharge under the First Lien Notes Indenture, (4) unless an event of default has occurred and is continuing, upon the dissolution or liquidation of a Guarantor in accordance with the First Lien Notes Indenture, and (5) if such Guarantor is properly designated as an unrestricted subsidiary, in each case in accordance with the provisions of the First Lien Notes Indenture.
Valaris conducts itsWe conduct our operations primarily through itsour subsidiaries. As a result, itsour ability to pay principal and interest on the First Lien Notes is dependent on the cash flow generated by itsour subsidiaries and their ability to make such cash available to Valarisus by dividend or otherwise. The Guarantors’ earnings will depend on their financial and operating performance, which will be affected by general economic, industry, financial, competitive, operating, legislative, regulatory and other factors beyond Valaris’stheir control. Any payments of dividends, distributions, loans or advances to Valarisus by the Guarantors could also be subject to restrictions on dividends under applicable local law
in the jurisdictions in which the Guarantors operate. In the event that Valaris doeswe do not receive distributions from the Guarantors, or to the extent that the earnings from, or other available assets of, the Guarantors are insufficient, Valariswe may be unable to make payments on the First Lien Notes.
Pledged Securities of Affiliates
Pursuant to the terms of the First Lien Notes collateral documents, the Collateral Agent under the First Lien Notes Indenture may pursue remedies, or pursue foreclosure proceedings on the Collateral (including the equity of the Guarantors and other direct subsidiaries of Valaris Limited and the Guarantors), following an event of default under the First Lien Notes Indenture. The Collateral Agent’s ability to exercise such remedies is limited by the intercreditor agreement for so long as any priority lien debt is outstanding.
The combined value of the affiliates whose securities are pledged as Collateral constitutes substantially all of the Company’s value, including assets, liabilities and results of operations. As such, the assets, liabilities and results of operations of the combined affiliates whose securities are pledged as Collateral are not materially different than the corresponding amounts presented in the consolidated financial statements of the Company. The value of the pledged equity is subject to fluctuations based on factors that include, among other things, general economic conditions and the ability to realize on the Collateral as part of a going concern and in an orderly fashion to available and willing buyers and outside of distressed circumstances. There is no trading market for the pledged equity interests.
Under the terms of the First Lien Notes Indenture and the other documents governing the obligations with respect to the First Lien Notes (the “Notes Documents”), Valaris Limited and the Guarantors will be entitled to the release of the Collateral from the liens securing the First Lien Notes under one or more circumstances, including (1) upon full and final payment of any such obligations; (2) to the extent that proceeds continue to constitute Collateral, in the event that Collateral is sold, transferred, disbursed or otherwise disposed of in accordance with the Notes Documents; (3) upon Valaris’sour exercise of legal defeasance, covenant defeasance or discharge under the First Lien Notes Indenture; (4) with respect to vessels, certain specified events permitting release of the mortgage with respect to such vessels under the First Lien Notes Indenture; (5) with the consent of the requisite holders under the First Lien Notes Indenture; (6) with respect to equity interests in restricted subsidiaries that incur permitted indebtedness, if such equity interests shall secure such other indebtedness and the same is permitted under the terms of the First Lien Notes Indenture; and (7) as provided in the intercreditor agreement. The collateral agency agreement also provides for release of the Collateral from the liens securing the Notes under the above described circumstances (but including additional requirements for release in relation to all of the documents governing the indebtedness that is secured by first-priority liens on the Collateral, in addition to the First Lien Notes Indenture). Upon the release of any subsidiary from its guarantee, if any, in accordance with the terms of the First Lien Notes Indenture, the lien on any pledged equity interests issued by such Guarantor and on any assets of such Guarantor will automatically terminate.
Summarized Financial Information
The summarized financial information below reflects the combined accounts of the Guarantors and Valaris Limited (collectively, the “Obligors”), for the dates and periods indicated. The financial information is presented on a combined basis and intercompany balances and transactions between entities in the Obligor group have been eliminated.
Summarized Balance Sheet Information:
| | | | | | | | | | | | | | |
| Successor | | | Predecessor |
| (in millions) | June 30,
2021 | | | December 31, 2020 |
| ASSETS | | | | |
| Current assets | $ | 1,134.2 | | | | $ | 901.8 | |
| Amounts due from non-guarantor subsidiaries, current | 744.3 | | | | 756.5 | |
| Amounts due from related party, current | 16.1 | | | | 20.5 | |
| Noncurrent assets | 1,014.5 | | | | 10,514.5 | |
| Amounts due from non-guarantor subsidiaries, noncurrent | 1,472.5 | | | | 4,879.2 | |
| LIABILITIES AND SHAREHOLDER'S EQUITY | | | | |
| Current liabilities | 354.9 | | | | 369.4 | |
| Amounts due from non-guarantor subsidiaries, current | 62.0 | | | | 865.5 | |
| Long Term Debt | 544.8 | | | | — | |
| Noncurrent liabilities | 463.8 | | | | 653.4 | |
| Amounts due from non-guarantor subsidiaries, noncurrent | 2,255.9 | | | | 7,848.6 | |
| Noncontrolling interest | .9 | | | | (4.4) | |
| | | | | | | | | | | | | | |
| | | | |
| (in millions) | March 31,
2022 | | | December 31, 2021 |
| ASSETS | | | | |
| Current assets | $ | 1,094.7 | | | | $ | 1,140.2 | |
| Amounts due from non-guarantor subsidiaries, current | 693.8 | | | | 785.8 | |
| Amounts due from related party, current | 12.0 | | | | 13.1 | |
| Noncurrent assets | 1,008.5 | | | | 989.8 | |
| Amounts due from non-guarantor subsidiaries, noncurrent | 1,469.7 | | | | 1,469.7 | |
| LIABILITIES AND SHAREHOLDER'S EQUITY | | | | |
| Current liabilities | 374.3 | | | | 308.0 | |
| Amounts due to non-guarantor subsidiaries, current | 10.9 | | | | 55.3 | |
| Amounts due to related party, current | 37.1 | | | | 38.3 | |
| Long-term debt | 545.5 | | | | 545.3 | |
| Noncurrent liabilities | 444.3 | | | | 438.5 | |
| Amounts due to non-guarantor subsidiaries, noncurrent | 1,922.5 | | | | 1,921.6 | |
| Noncontrolling interest | 1.4 | | | | 2.6 | |
Summarized Statement of Operations Information:
| | | Successor | | | Predecessor | | Successor | | | | Predecessor |
| (in millions) | (in millions) | Two Months Ended June 30, 2021 | | | One Month Ended April 30, 2021 | Three Months Ended June 30, 2020 | (in millions) | Three Months Ended March 31, 2022 | | | | Three Months Ended March 31, 2021 |
| Operating revenues | Operating revenues | $ | 216.6 | | | | $ | 80.5 | | $ | 411.8 | | Operating revenues | $ | 299.9 | | | | | $ | 314.7 | |
| Operating revenues from related party | Operating revenues from related party | 10.8 | | | | 5.4 | | 20.7 | | Operating revenues from related party | 14.3 | | | | | 17.8 | |
| Operating costs and expenses | Operating costs and expenses | 192.5 | | | | 126.3 | | 1,382.4 | | Operating costs and expenses | 349.5 | | | | | 1,148.4 | |
| Reorganization expense | Reorganization expense | (4.1) | | | | (3,532.4) | | — | | Reorganization expense | (1.0) | | | | | (51.6) | |
| Income (loss) from continuing operations before income taxes | 173.8 | | | | (3,487.9) | | (914.2) | | |
| Loss from continuing operations before income taxes | | Loss from continuing operations before income taxes | (65.0) | | | | | (849.2) | |
| Net income (loss) attributable to noncontrolling interest | Net income (loss) attributable to noncontrolling interest | (2.1) | | | | (.8) | | 1.3 | | Net income (loss) attributable to noncontrolling interest | 1.2 | | | | | (2.4) | |
| Net income (loss) | 171.7 | | | | (3,488.7) | | (912.9) | | |
| Net loss | | Net loss | (63.9) | | | | | (851.6) | |
MARKET RISK
Interest Rate Risk
| | | | | | | | | | | | | | | | | |
| Successor | | | Predecessor |
| (in millions) | Two Months Ended June 30, 2021 | | | Four Months Ended April 30, 2021 | Six Months Ended June 30, 2020 |
| Operating revenues | $ | 216.6 | | | | $ | 384.1 | | $ | 830.9 | |
| Operating revenues from related party | 10.8 | | | | 23.1 | | 50.5 | |
| Operating costs and expenses | 192.5 | | | | 1,262.2 | | 4,812.0 | |
| Reorganization expense | (4.1) | | | | (3,584.1) | | — | |
| Income (loss) from continuing operations before income taxes | 173.8 | | | | (4,337.0) | | (3,757.7) | |
| Net income (loss) attributable to noncontrolling interest | (2.1) | | | | (3.2) | | 2.8 | |
| Net income (loss) | 171.7 | | | | (4,340.2) | | (3,754.9) | |
Our long-term notes receivable from ARO bear interest based on a one-year LIBOR rate, set as of the end of the year prior to the year applicable, plus two percent. As the notes bear interest on the LIBOR rate determined at the end of the preceding year, the rate governing our interest income in 2022 has already been determined.
A hypothetical 1% decrease to LIBOR would decrease our interest income by approximately $4.4 million based on the principal amount outstanding at March 31, 2022 of $442.7 million.
Foreign Currency 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 are exposed to foreign currency exchange risk to the extent the amount of our monetary assets denominated in the foreign currency differs from our obligations in the foreign currency or revenue earned differs from costs incurred in the foreign currency. We do not currently hedge our foreign currency risk as our unsecured foreign currency credit lines were terminated in the second quarter of 2020 and our access to other foreign currency credit lines is limited.
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, 2020,2021, included in our annual report on Form 10-K filed with the SEC on March 2, 2021.February 22, 2022. 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 regarding estimates in matters that are inherently uncertain. Our critical accounting policies are those related to property and equipment, impairment of property and equipment for the Predecessor, 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, 2020.2021.Concurrent with our emergence from bankruptcy, we adopted fresh start accounting and elected to change the accounting policies related to property and equipment as well as materials and supplies. See "Note 1, Unaudited Condensed Consolidated Financial Statements" to our condensed consolidated financial statements included in "Part I, Item 1. Financial Statements" for more information.
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.Information required under this Item 3. has been incorporated herein from "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations - Market Risk."
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 June 30, 2021,March 31, 2022, our management, with the participation of 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 – During the second quarter of 2021, upon emergence from Chapter 11, we established controls over the application of fresh start accounting. Except for such application of fresh start accounting, thereThere have been no material changes in our internal controls over financial reporting during the fiscal
quarter ended June 30, 2021March 31, 2022 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
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 alleged, 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 the Predecessor’s now terminated Revolving Credit Facility. In addition to an unspecified amount of damages, the lawsuit sought 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 restructuring support agreement, including the noteholders that directed UMB to file the lawsuit. Under the restructuring support agreement, the lawsuit was stayed by agreement throughout the pendency of the bankruptcy proceeding unless the restructuring support agreement terminated at which point each party reserved 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. Because the chapter 11 plan of reorganization was confirmed by the Bankruptcy Court and was consummated, the lawsuit was dismissed with prejudice.
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. After the court appointed a lead plaintiff and lead counsel, the case was stayed in light of the Valaris plc bankruptcy filing. Lead plaintiff submitted a general unsecured claim in Valaris plc’s chapter 11 case. On June 10, 2021, the Bankruptcy Court granted Valaris plc’s motion to subordinate the claim to a class that was not entitled to receive any recovery in the bankruptcy. On June 16, 2021, the Bankruptcy Court also granted Valaris plc’s motion to enforce the releases and injunction under its plan of reorganization and require lead plaintiff to dismiss the lawsuit as to the remaining defendants. Accordingly, on July 8, 2021, lead plaintiff filed a notice of voluntary dismissal of his claims with prejudice.
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 2020, pursuant to which the governmental authorities have assessed, or are anticipated to assess, fines. We have contested these notices and appealed certain adverse decisions and are awaiting decisions in these cases. Although we do not expect final disposition of these assessments to have a material adverse effect on our financial position, operating results and cash flows, there can be no assurance as to the ultimate outcome of these assessments. A $0.5 million liability related to these matters was included in accruedAccrued liabilities and other on our Condensed Consolidated Balance Sheet as of June 30, 2021.March 31, 2022 included in "Item 1. Financial Statements."
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 the other information set forthpresented 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, 2020,2021, which contains descriptions of significant risks that may cause our actual results of operations in future periods to differ materially from those currently anticipated or expected.
We recently emerged from bankruptcy, which may adversely affect our business and relationships.
It is possible that our having filed for bankruptcy and our recent emergence from the Chapter 11 Cases may adversely affect our business and relationships with our vendors, suppliers, service providers, customers, employees and other third parties. Many risks exist as a result of the Chapter 11 Cases and our emergence, including the following:
•we may have difficulty obtaining acceptable and sufficient financing to execute our business plan;
•key suppliers, vendors and customers, may among other things, renegotiate the terms of our agreements, attempt to terminate their relationship with us or require financial assurances from us;
•our ability to renew existing contracts and obtain new contracts on reasonably acceptable terms and conditions may be adversely affected;
•our ability to attract, motivate and retain key employees and executives may be adversely affected; and
•competitors may take business away from us, and our ability to compete for new business and attract and retain customers may be negatively impacted.
The occurrence of one or more of these events could have a material and adverse effect on our operations, financial condition and reputation. We cannot assure you that having been subject to bankruptcy protection will not adversely affect our operations in the future.
Our actual financial results after emergence from bankruptcy may not be comparable to our projections filed with the Bankruptcy Court in the course of the Chapter 11 Cases.
In connection with the disclosure statement we filed with the Bankruptcy Court and the hearing to consider confirmation of the plan of reorganization, we prepared projected financial information to demonstrate to the Bankruptcy Court the feasibility of the plan of reorganization and our ability to continue operations upon our emergence from the Chapter 11 Cases. Those projections were prepared solely for the purpose of the Chapter 11 Cases and have not been and will not be updated and should not be relied upon by investors. At the time they were prepared, the projections reflected numerous assumptions concerning our anticipated future performance with respect to then prevailing and anticipated market and economic conditions that were and remain beyond our control and that may not materialize. We have not reviewed the projections or the assumptions on which they were based after our emergence. Projections are inherently subject to substantial and numerous uncertainties and to a wide variety of significant business, economic and competitive risks, and the assumptions underlying the projections or valuation estimates may prove to be wrong in material respects. Actual results may vary significantly from those contemplated by the projections. As a result, investors should not rely on these projections.
Our historical financial information will not be indicative of future financial performance as a result of the implementation of the plan of reorganization and the transactions contemplated thereby, as well as our application of fresh start accounting following emergence.
Our capital structure was significantly impacted by the plan of reorganization. Under fresh start accounting rules that we applied on the Effective Date, assets and liabilities will be adjusted to fair values and our accumulated deficit will be reset to zero. Accordingly, as a result of the application of fresh start accounting, our financial condition and results of operations following emergence from the Chapter 11 Cases will not be comparable to the financial condition and results of operations reflected in our historical financial statements on or prior to the Effective Date.
The exercise of all or any number of outstanding warrants or the issuance of stock-based awards may dilute the holders of our common shares.
On the Effective Date, we issued 75,000,000 common shares and 5,645,161 Warrants to purchase 5,645,161 common shares at an exercise price of $131.88 per share, exercisable for a seven years period commencing on that date. Additionally, on May 3, 2021, our board of directors approved and ratified the Valaris Limited 2021 Management Incentive Plan (the “MIP”) and reserved 8,960,573 of our common shares for issuance under awards to be made under the MIP primarily for employees and directors. The grant of equity awards in the future, any exercise of the Warrants into common shares and any sale of common shares underlying outstanding Warrants would have a dilutive effect to the holdings of our existing shareholders and could have an adverse effect on the market for our common shares, including the price that an investor could obtain for their common shares.
Our ability to make payments due on our debt depends on many factors beyond our control.
Our ability to pay our operating and capital expenses and make payments due on our debt depends on our future performance, which will be affected by financial, business, economic, legislative and other factors, many of which are beyond our control. The First Lien Notes contain payment-in-kind interest provisions, which reduce the cash needed to pay interest while increasing the principal amount of First Lien Notes that ultimately must be retired with a cash payment. Our business may not generate sufficient cash flow from operations in the future, which could result in our being unable to repay indebtedness or to fund other liquidity needs. A range of economic, competitive, business and industry factors will affect our future financial performance, and many of these factors, such as the economic and financial condition of our industry, the global economy and initiatives of its competitors, are beyond our control. If we do not generate enough cash flow from operations to satisfy our debt obligations, we may have to undertake alternative financing plans, such as:
•selling assets;
•reducing or delaying capital investments;
•seeking to raise additional capital; or
•restructuring or refinancing all or a portion of our indebtedness at or before maturity.
We cannot assure you that we will be able to accomplish any of these alternatives on terms acceptable to us or at all. In addition, the terms of existing or future debt agreements may restrict us from adopting any of these alternatives. The failure to generate sufficient cash flow or to achieve any of these alternatives could materially adversely affect our ability to pay the amounts due under our debt.
The indenture governing the First Lien Notes contains operating and financial restrictions that restrict our business and financing activities and could limit our growth.
The primary restrictive covenants contained in the indenture governing the First Lien Notes limit our ability to, among other things:
•incur additional indebtedness;
•sell or convey assets;
•make loans to or investments in others;
•enter into mergers;
•make certain payments;
•incur liens; and
•pay dividends.
We may also be prevented from taking advantage of business opportunities that arise because of the limitations that the restrictive covenants imposed on us by the indenture.
Increased scrutiny from stakeholders and others regarding our ESG practices and reporting responsibilities could result in additional costs or risks and adversely impact our business and reputation.
Environmental, Social and Governance (ESG) matters have been the subject of increased focus by investors, investment funds and other market and industry participants, as well as certain regulators, including in the U.S. and the EU. We publish an annual Sustainability Report, which includes disclosure of our ESG practices and goals. We anticipate that we will publish our 2020 Sustainability Report in September 2021. Our disclosures on these matters or a failure to meet these goals or evolving stakeholder expectations for ESG practices and reporting may potentially harm our reputation and impact employee retention, customer relationships and access to capital. By electing to set and share publicly our corporate ESG standards, our business may also face increased scrutiny related to ESG activities. As ESG best-practices and reporting standards continue to develop, we may incur increasing costs related ESG monitoring and reporting and complying with ESG initiatives.
We are a Bermuda company and it may be difficult to enforce judgments against us or our directors and executive officers.
We are a Bermuda exempted company. As a result, the rights of holders of our common shares are governed by Bermuda law and our memorandum of association and bye-laws. The rights of shareholders under Bermuda law may differ from the rights of shareholders of companies incorporated in other jurisdictions. Some of our directors and officers are not residents of the United States, and a substantial portion of our assets are located outside the United States. As a result, it may be difficult for investors to effect service of process on those persons in the United States or to enforce in the United States judgments obtained in U.S. courts against us or those persons based on the civil liability provisions of the U.S. securities laws. It is doubtful whether courts in Bermuda will enforce judgments obtained in other jurisdictions, including the United States, against us or our directors or officers under the securities laws of those jurisdictions or entertain actions in Bermuda against us or our directors or officers under the securities laws of other jurisdictions.
Our bye-laws restrict shareholders from bringing legal action against our officers and directors.
Our bye-laws contain a broad waiver by our shareholders of any claim or right of action, both individually and on our behalf, against any of our officers or directors. The waiver applies to any action taken by an officer or director, or the failure of an officer or director to take any action, in the performance of his or her duties, except with respect to any matter involving any fraud or dishonesty on the part of the officer or director. This waiver limits the right of shareholders to assert claims against our officers and directors unless the act or failure to act involves fraud or dishonesty.
Legislation enacted in Bermuda as to Economic Substance may affect our operations.
Pursuant to the Economic Substance Act 2018 (as amended) of Bermuda (the “ES Act”) that came into force on January 1, 2019, a registered entity other than an entity which is resident for tax purposes in certain jurisdictions outside Bermuda (“non-resident entity”) that carries on as a business any one or more of the “relevant activities” referred to in the ES Act must comply with economic substance requirements. The ES Act may require in-scope Bermuda entities which are engaged in such “relevant activities” to be directed and managed in Bermuda, have an adequate level of qualified employees in Bermuda, incur an adequate level of annual expenditure in Bermuda, maintain physical offices and premises in Bermuda or perform core income-generating activities in Bermuda. The list of “relevant activities” includes carrying on any one or more of: banking, insurance, fund management, financing, leasing, headquarters, shipping, distribution and service center, intellectual property and holding entities. The ES Act could affect the manner in which we operate our business, which could adversely affect our business, financial condition and results of operations.
Provisions in our bye-laws could delay or prevent a change in control of our company, which could adversely affect the price of our common shares.
The existence of some provisions in our bye-laws could delay or prevent a change in control of our company that a shareholder may consider favorable, which could adversely affect the price of our common shares. Certain provisions of our bye-laws could make it more difficult for a third party to acquire control of our company, even if the change of control would be beneficial to our shareholders. These provisions include:
•authority of our board to determine its size;
•the ability of our board of directors to issue preferred shares without shareholder approval;
•limitations on the removal of directors; and
•limitations on the ability of our shareholders to act by written consent in lieu of a meeting.
In addition, our bye-laws establish advance notice provisions for shareholder proposals and nominations for elections to the board of directors to be acted upon at meetings of shareholders.
Our current backlog of contract drilling revenue may not be fully realized and may decline significantly in the future.
As of August 2, 2021, our contract backlog was approximately $2.2 billion and $1.0 billion as of December 31, 2020. This amount reflects the remaining contractual terms multiplied by the applicable contractual day rate. The contractual revenue may be higher than the actual revenue we ultimately receive because of a number of factors, including rig downtime or suspension of operations. Several factors could cause rig downtime or a suspension of operations, many of which are beyond our control, including:
•the early termination, repudiation or renegotiation of contracts,
•breakdowns of equipment,
•work stoppages, including labor strikes,
•shortages of material or skilled labor,
•surveys by government and maritime authorities,
•periodic classification surveys,
•severe weather, strong ocean currents or harsh operating conditions,
•the occurrence or threat of epidemic or pandemic diseases and any government response to such occurrence or threat, and
•force majeure events.
Our customers may seek to terminate, repudiate or renegotiate our drilling contracts for various reasons, including in the event of a total loss of the drilling rig, the suspension or interruption of operations for extended periods due to breakdown of major rig equipment, failure to comply with performance conditions or equipment specifications, "force majeure" events, the failure of the customer to receive final investment decision (FID) with
respect to projects for which the drilling rig was contracted or other specified events. Generally, our drilling contracts permit early termination of the contract by the customer for convenience (without cause), exercisable upon advance notice to us, and in certain cases without making an early termination payment to us. There can be no assurances that our customers will be able to or willing to fulfill their contractual commitments to us.
The decline in oil prices and the resulting downward pressure on utilization has caused and may continue to cause some customers to consider early termination of select contracts despite having to pay onerous early termination fees in certain cases. Customers may continue to request to renegotiate the terms of existing contracts, or they may request early termination or seek to repudiate contracts in some circumstances. Furthermore, as our existing contracts expire, we may be unable to secure new contracts for our rigs. Therefore, revenues recorded in future periods could differ materially from our current backlog. Our inability to realize the full amount of our contract backlog may have a material adverse effect on our financial position, operating results or cash flows.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
The following table provides a summary of our repurchases of our equity securities during the quarter ended June 30, 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 (3) | | Approximate Dollar Value of Securities that May Yet Be Repurchased Under Plans or Programs (3) |
| | | | | | | | |
April 1 - April 30 (2) | | 1,057 | | | $ | 0.07 | | | — | | | $ | 500,000,000 | |
| | | | | | | | |
| May 1 - May 31 | | — | | | $ | — | | | — | | | — | |
| June 1 - June 30 | | — | | | $ | — | | | — | | | — | |
| Total | | 1,057 | | | $ | 0.07 | | | — | | | |
(1)During the month of April 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.
(2)On the Effective Date and pursuant to the terms of the plan of reorganization, all Legacy Valaris ordinary shares were cancelled. Furthermore, all agreements, instruments and other documents evidencing, relating or otherwise connected with any of Legacy Valaris' equity interests outstanding prior to the Effective Date, including all equity-based awards, were cancelled.
(3)Since the Effective Date, we have not had, and currently do not have, a share repurchase program in place.
Item 6. Exhibits
| | | | | | | | | | | |
| Exhibit Number | | Exhibit | |
3.1 | | | |
3.2 | | | |
| | | | | | | | | | | |
| 4.1 | | | |
4.2 | | FirstSecond Supplemental Indenture, dated as of July 6, 2021,January 12, 2022, among Valaris Limited, Alpha South Pacific Holding Company,Valaris United LLC, and Wilmington Savings Fund, FSB as collateral agent and trustee (incorporated by reference to Exhibit 4.24.4 to the Company’s Amendment No. 9 to the Registration StatementRegistrant’s Annual Report on Form S-110-K filed on July 7, 2021,February 22, 2022, File No. 333-257022)001-08097). | |
| *10.1 | | | |
| 10.2 | | | |
10.3 | | | |
10.4 | | | |
10.5 | | | |
10.6 | | | |
*10.722.1 | | | |
*10.8 | | | |
| *31.1 | | | |
| *31.2 | | | |
| **32.1 | | | |
| **32.2 | | | |
| *101.INS | | XBRL 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.SCH | | Inline XBRL Taxonomy Extension Schema Document | |
| *101.CAL | | Inline XBRL Taxonomy Extension Calculation Linkbase Document | |
| *101.DEF | | Inline XBRL Taxonomy Extension Definition Linkbase Document | |
| *101.LAB | | Inline XBRL Taxonomy Extension Label Linkbase Document | |
| *101.PRE | | Inline XBRL Taxonomy Extension Presentation Linkbase Document | |
| *104 | | The cover page of our Quarterly Report on Form 10-Q for the quarter ended June 30, 2021,March 31, 2022, formatted in Inline XBRL (included with Exhibit 101 attachments). | |
* Filed herewith.
** Furnished herewith.
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 Limited |
| | | | |
| | | | |
| Date: | AugustMay 3, 20212022 | | /s/ JONATHAN H. BAKSHTDARIN GIBBINS |
| | | Jonathan H. BakshtDarin Gibbins
ExecutiveInterim Chief Financial Officer and Vice President, Investor Relations and
Chief Financial Officer
(principal financial officer) |
| | | |
| | | /s/ COLLEEN W. GRABLE |
| | | Colleen W. Grable
Controller
(principal accounting officer) |