10-Q

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, 2022


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

For the transition period from to

Commission file number 1-13926

DIAMOND OFFSHORE DRILLING, INC.

(Exact name of registrant as specified in its charter)

Delaware

76-0321760

(State or other jurisdiction of incorporation
or organization)

(I.R.S. Employer
Identification No.)

15415 Katy Freeway

Houston, Texas

77094

(Address of principal executive offices)

(Zip Code)

(281) 492-5300

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Exchange Act:


Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, $0.0001 par value per share	DO	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 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 Sections 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 ☐

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

As of August 8, 2022 Common stock, $0.0001 par value per share 101,381,096 shares

DIAMOND OFFSHORE DRILLING, INC.

TABLE OF CONTENTS FOR FORM 10-Q

QUARTER ENDED JUNE 30, 2022


			PAGE NO.

COVER PAGE			1

TABLE OF CONTENTS			2

PART I. FINANCIAL INFORMATION			3

	ITEM 1.	Financial Statements (Unaudited)	3
		Condensed Consolidated Balance Sheets	3
		Condensed Consolidated Statements of Operations	4
		Condensed Consolidated Statements of Stockholders’ Equity	6
		Condensed Consolidated Statements of Cash Flows	8
		Notes to Unaudited Condensed Consolidated Financial Statements	9

	ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	21

	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	33

	ITEM 4.	Controls and Procedures	33

PART II. OTHER INFORMATION			34

	ITEM 1.	Legal Proceedings	34
			34
	ITEM 1A.	Risk Factors

	ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	34

	ITEM 6.	Exhibits	35

SIGNATURES			36

PART I. FINANCIAL INFORMATION

ITEM 1. Financial Statements.

DIAMOND OFFSHORE DRILLING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In thousands, except par value amounts)


	Successor
	June 30,			December 31,
	2022			2021
ASSETS
Current assets:
Cash and cash equivalents	$	42,897		$	38,388
Restricted cash		14,727			24,341
Accounts receivable		156,984			151,917
Less: allowance for credit losses		(5,610	)		(5,582	)
Accounts receivable, net		151,374			146,335
Prepaid expenses and other current assets		65,871			61,440
Asset held for sale		—			1,000
Total current assets		274,869			271,504
Drilling and other property and equipment, net of
accumulated depreciation		1,159,535			1,175,895
Other assets		80,319			84,041
Total assets	$	1,514,723		$	1,531,440
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	48,942		$	38,661
Accrued liabilities		145,730			143,736
Taxes payable		26,774			34,500
Current finance lease liabilities		16,401			15,865
Total current liabilities		237,847			232,762
Long-term debt		306,438			266,241
Noncurrent finance lease liabilities		140,087			148,358
Deferred tax liability		2,306			1,626
Other liabilities		104,193			114,748
Commitments and contingencies (Note 8)
Total liabilities		790,871			763,735
Stockholders’ equity:
Preferred stock (par value $0.0001, 50,000 shares authorized, none issued and outstanding at June 30, 2022 and December 31, 2021)		—			—
Common stock (par value $0.0001, 750,000 shares authorized; 100,149 shares issued and 100,131 shares outstanding at June 30, 2022 and 100,075 shares issued and outstanding at December 31, 2021)		10			10
Additional paid-in capital		957,608			945,039
Treasury stock		(139	)		—
Accumulated deficit		(233,627	)		(177,344	)
Total stockholders’ equity		723,852			767,705
Total liabilities and stockholders’ equity	$	1,514,723		$	1,531,440

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

DIAMOND OFFSHORE DRILLING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands, except per share data)


	Successor						Predecessor
				Period from			Period from
	Three Months			April 24, 2021			April 1, 2021
	Ended			through			through
	June 30, 2022			June 30, 2021			April 23, 2021
Revenues:
Contract drilling	$	176,879		$	98,033		$	30,811
Revenues related to reimbursable expenses		28,823			16,878			3,751
Total revenues		205,702			114,911			34,562
Operating expenses:
Contract drilling, excluding depreciation		142,150			90,711			40,053
Reimbursable expenses		28,554			16,572			3,640
Depreciation		25,693			18,735			18,132
General and administrative		19,753			16,217			2,670
Gain on disposition of assets		(685	)		(176	)		(85	)
Total operating expenses		215,465			142,059			64,410
Operating loss		(9,763	)		(27,148	)		(29,848	)
Other income (expense):
Interest income		—			1			—
Interest expense, net of amounts capitalized (excludes $7,124 of contractual interest expense on debt subject to compromise for the period from April 1, 2021 through April 23, 2021)		(10,103	)		(7,097	)		(2,265	)
Foreign currency transaction gain (loss)		1,607			(914	)		(797	)
Reorganization items, net		—			(5,538	)		(1,604,512	)
Other, net		(47	)		10,706			(90	)
Loss before income tax (expense) benefit		(18,306	)		(29,990	)		(1,637,512	)
Income tax (expense) benefit		(3,623	)		(17,303	)		37,204
Net loss	$	(21,929	)	$	(47,293	)	$	(1,600,308	)
Loss per share, Basic and Diluted	$	(0.22	)	$	(0.47	)	$	(11.59	)
Weighted-average shares outstanding, Basic and Diluted		100,108			100,059			138,054

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

DIAMOND OFFSHORE DRILLING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands, except per share data)


	Successor						Predecessor
				Period from			Period from
	Six Months			April 24, 2021			January 1, 2021
	Ended			through			through
	June 30, 2022			June 30, 2021			April 23, 2021
Revenues:
Contract drilling	$	327,131		$	98,033		$	153,364
Revenues related to reimbursable expenses		64,810			16,878			16,015
Total revenues		391,941			114,911			169,379
Operating expenses:
Contract drilling, excluding depreciation		287,052			90,711			181,626
Reimbursable expenses		64,167			16,572			15,477
Depreciation		52,645			18,735			92,758
General and administrative		36,485			16,217			15,036
Impairment of assets		—			—			197,027
Gain on disposition of assets		(4,729	)		(176	)		(5,486	)
Total operating expenses		435,620			142,059			496,438
Operating loss		(43,679	)		(27,148	)		(327,059	)
Other income (expense):
Interest income		1			1			30
Interest expense, net of amounts capitalized (excludes $35,390 of contractual interest expense on debt subject to compromise for the period from January 1, 2021 through April 23, 2021)		(18,428	)		(7,097	)		(34,827	)
Foreign currency transaction gain (loss)		(522	)		(914	)		(172	)
Reorganization items, net		—			(5,538	)		(1,639,763	)
Other, net		1,315			10,706			398
Loss before income tax benefit (expense)		(61,313	)		(29,990	)		(2,001,393	)
Income tax benefit (expense)		5,030			(17,303	)		39,404
Net loss	$	(56,283	)	$	(47,293	)	$	(1,961,989	)
Loss per share, Basic and Diluted	$	(0.56	)	$	(0.47	)	$	(14.21	)
Weighted-average shares outstanding, Basic and Diluted		100,092			100,059			138,054

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

DIAMOND OFFSHORE DRILLING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Unaudited)

(In thousands)


	Three Months Ended June 30, 2022
					Additional										Total
	Common Stock				Paid-In		Accumulated			Treasury Stock					Stockholders’
	Shares		Amount		Capital		Deficit			Shares		Amount			Equity
April 1, 2022 (Successor)		100,075	$	10	$	949,511	$	(211,698	)		—	$	—		$	737,823
Net loss		—		—		—		(21,929	)		—		—			(21,929	)
Stock-based compensation, net of tax		56		—		8,097		—			18		(139	)		7,958
June 30, 2022 (Successor)		100,131	$	10	$	957,608	$	(233,627	)		18	$	(139	)	$	723,852


	Six Months Ended June 30, 2022
					Additional										Total
	Common Stock				Paid-In		Accumulated			Treasury Stock					Stockholders’
	Shares		Amount		Capital		Deficit			Shares		Amount			Equity
January 1, 2022 (Successor)		100,075	$	10	$	945,039	$	(177,344	)		—	$	—		$	767,705
Net loss		—		—		—		(56,283	)		—		—			(56,283	)
Stock-based compensation, net of tax		56		—		12,569					18		(139	)		12,430
June 30, 2022 (Successor)		100,131	$	10	$	957,608	$	(233,627	)		18	$	(139	)	$	723,852

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

DIAMOND OFFSHORE DRILLING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Unaudited)

(In thousands)


	Three Months Ended June 30, 2021
							Additional												Total
	Common Stock						Paid-In			Accumulated			Treasury Stock						Stockholders’
	Shares			Amount			Capital			Deficit			Shares			Amount			Equity
April 1, 2021 (Predecessor)		145,264		$	1,453		$	2,029,979		$	(204,384	)		7,210		$	(206,163	)	$	1,620,885
Net loss		—			—			—			(1,600,308	)		—			—			(1,600,308	)
Cancellation of Predecessor equity		(145,264	)		(1,453	)		(2,029,979	)		1,804,692			(7,210	)		206,163			(20,577	)
April 23, 2021 (Predecessor)		—			—			—			—			—			—			—


Issuance of Successor equity		100,000			10			934,800			—			—			—			934,810
April 24, 2021 (Successor)		100,000			10			934,800			—			—			—			934,810
Net loss		—			—			—			(47,293	)		—			—			(47,293	)
Stock-based compensation, net of tax		75			—			992			—			—			—			992
June 30, 2021 (Successor)		100,075		$	10		$	935,792		$	(47,293	)		—		$	—		$	888,509


	Six Months Ended June 30, 2021
							Additional			Retained Earnings									Total
	Common Stock						Paid-In			(Accumulated			Treasury Stock						Stockholders’
	Shares			Amount			Capital			Deficit)			Shares			Amount			Equity
January 1, 2021 (Predecessor)		145,264		$	1,453		$	2,029,979		$	157,297			7,210		$	(206,163	)	$	1,982,566
Net loss		—			—			—			(1,961,989	)		—			—			(1,961,989	)
Cancellation of Predecessor equity		(145,264	)		(1,453	)		(2,029,979	)		1,804,692			(7,210	)		206,163			(20,577	)
April 23, 2021 (Predecessor)		-		$	-		$	-		$	—			—		$	—		$	-


Issuance of Successor equity		100,000			10			934,800												934,810
April 24, 2021 (Successor)		100,000		$	10		$	934,800		$	—			—		$	—		$	934,810
Net loss		—			—			—			(47,293	)		—			—			(47,293	)
Stock-based compensation, net of tax		75			—			992			—			—			—			992
June 30, 2021 (Successor)		100,075		$	10		$	935,792		$	(47,293	)		—		$	—		$	888,509

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

DIAMOND OFFSHORE DRILLING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)


	Successor						Predecessor
				Period from			Period from
	Six Months Ended			April 24, 2021			January 1, 2021
	June 30,			through			through
	2022			June 30, 2021			April 23, 2021
Operating activities:
Net loss	$	(56,283	)	$	(47,293	)	$	(1,961,989	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation		52,645			18,735			92,758
Loss on impairment of assets		—			—			197,027
Reorganization items, net		—			—			1,587,392
Gain on disposition of assets		(4,729	)		(176	)		(5,486	)
Deferred tax provision		(1,975	)		9,952			(35,894	)
Stock-based compensation expense		12,658			1,134			—
Contract liabilities, net		(20,870	)		23,572			10,617
Contract assets, net		(3,348	)		(509	)		(742	)
Deferred contract costs, net		(3,859	)		(14,987	)		(12,034	)
Collateral deposits		17,464			—			—
Other assets, noncurrent		(443	)		(1,426	)		2,685
Other liabilities, noncurrent		428			458			(371	)
Other		842			654			3,158
Changes in operating assets and liabilities:
Accounts receivable		(5,039	)		(53,759	)		2,108
Prepaid expenses and other current assets		(9,417	)		(26	)		(2,791	)
Accounts payable and accrued liabilities		28,832			(9,972	)		29,302
Taxes payable		(17,711	)		7,604			(5,804	)
Net cash used in operating activities		(10,805	)		(66,039	)		(100,064	)
Investing activities:
Capital expenditures		(32,353	)		(23,973	)		(49,119	)
Proceeds from disposition of assets, net of disposal costs		5,788			193			7,484
Net cash used in investing activities		(26,565	)		(23,780	)		(41,635	)
Financing activities:
Repayment of borrowings under revolving credit facility		—			—			(442,034	)
Proceeds from exit facilities		40,000			30,000			200,000
Issuance of exit notes		—			—			75,000
Principal payments of finance lease liabilities		(7,735	)		(2,240	)		—
Debt issuance costs and arrangement fees		—			—			(6,218	)
Net cash provided by (used in) financing activities		32,265			27,760			(173,252	)
Net change in cash, cash equivalents and restricted cash		(5,105	)		(62,059	)		(314,951	)
Cash, cash equivalents and restricted cash, beginning of period		62,729			115,429			430,380
Cash, cash equivalents and restricted cash, end of period	$	57,624		$	53,370		$	115,429

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

DIAMOND OFFSHORE DRILLING, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. General Information

The unaudited condensed consolidated financial statements of Diamond Offshore Drilling, Inc. and subsidiaries, which we refer to as “Diamond Offshore,” “Company,” “we,” “us” or “our,” should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2021, as amended by Amendment No. 1 on Form 10-K/A (File No. 1-13926). To facilitate our financial statement presentations, we refer to the post-emergence reorganized company in these unaudited condensed consolidated financial statements and footnotes as the “Successor” for periods subsequent to April 23, 2021 and to the pre-emergence company as the “Predecessor” for periods on or prior to April 23, 2021. This delineation between Predecessor periods and Successor periods is shown in the unaudited condensed consolidated financial statements, certain tables within the footnotes to the unaudited condensed consolidated financial statements and other parts of this Quarterly Report on Form 10-Q through the use of a black line, calling out the lack of comparability between periods.

Interim Financial Information

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities and Exchange Commission. Accordingly, pursuant to such rules and regulations, they do not include all disclosures required by GAAP for annual financial statements. The condensed consolidated financial information has not been audited but, in the opinion of management, includes all adjustments (consisting of normal recurring adjustments) necessary for a fair presentation of Diamond Offshore’s condensed consolidated balance sheets, statements of operations, statements of stockholders’ equity and statements of cash flows at the dates and for the periods indicated. Results of operations for interim periods are not necessarily indicative of results of operations for the respective full years.

Fresh Start Accounting

Upon our emergence from bankruptcy on April 23, 2021 (or the Effective Date), we met the criteria for and were required to adopt fresh start accounting in accordance with the Financial Accounting Standards Board (or FASB) Accounting Standards Codification Topic No. 852 – Reorganizations, which on the Effective Date resulted in a new entity, the Successor, for financial reporting purposes, with no beginning retained earnings or deficit as of the fresh start reporting date.

Fresh start accounting requires that new fair values be established for the Company’s assets, liabilities, and equity as of the Effective Date. The Effective Date fair values of the Successor’s assets and liabilities differ materially from their recorded values as reflected on the historical balance sheets of the Predecessor. In addition, as a result of the application of fresh start accounting and the effects of the implementation of our restructuring plan, the financial statements for periods after April 23, 2021 will not be comparable with the financial statements prior to and including April 23, 2021. References to “Successor” refer to the Company and its financial position and results of operations after the Effective Date (including December 31, 2021, June 30, 2022, the three-month and six-month periods ended June 30, 2022 and the period from April 24, 2021 through June 30, 2021). References to “Predecessor” refer to the Company and its financial position and results of operations on or before the Effective Date (including the period from January 1, 2021 through April 23, 2021 and the period from April 1, 2021 through April 23, 2021).

Use of Estimates in the Preparation of Financial Statements

The preparation of financial statements in conformity with generally accepted accounting principles (or GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amount of revenues and expenses during the reporting period. Actual results could differ from those estimated.

Restricted Cash

We maintain a restricted cash bank account which is subject to restrictions pursuant to a management and marketing services agreement with an offshore drilling company. See Note 2 “Revenue from Contracts with Customers.”

We classify such restricted cash accounts in current assets if the restrictions are expected to expire or otherwise be resolved within one year or if such funds are considered to offset current liabilities. At June 30, 2022 and December 31, 2021, our restricted cash was considered to be current and was recorded in “Restricted cash” in our unaudited Condensed Consolidated Balance Sheets.

2. Revenue from Contracts with Customers

The activities that primarily drive the revenue earned from our contract drilling services include (i) providing a drilling rig and the crew and supplies necessary to operate the rig, (ii) mobilizing and demobilizing the rig to and from the drill site and (iii) performing rig preparation activities and/or modifications required for the contract. Consideration received for performing these activities may consist of dayrate drilling revenue, mobilization and demobilization revenue, contract preparation revenue and reimbursement revenue. We account for these integrated services provided within our drilling contracts as a single performance obligation satisfied over time and comprised of a series of distinct time increments in which we provide drilling services.

Consideration for activities that are not distinct within the context of our contracts and do not correspond to a distinct time increment within the contract term are allocated across the single performance obligation and recognized ratably over the initial term of the contract (which is the period we estimate to be benefited from the corresponding activities and generally ranges from two to 60 months). Such consideration may include mobilization, demobilization, contract preparation and capital modification revenue that is stipulated in our drilling contracts. Consideration for activities that correspond to a distinct time increment within the contract term is recognized in the period when the services are performed. The total transaction price is determined for each individual contract by estimating both fixed and variable consideration expected to be earned over the term of the contract.

Revenues Related to Managed Rigs

In May 2021, we entered into an arrangement with Aquadrill LLC, an offshore drilling company, for us to provide management and marketing services (or the MMSA) for three of its rigs. In July 2022, we received notice of termination of the MMSA for one of these rigs, the West Capricorn. However, we will continue performing management services for this rig for a period of time pursuant to the notice of termination and the MMSA.

Per the MMSA, for stacked rigs we earn a daily service fee and are entitled to reimbursement of direct costs incurred in accordance with the agreement. For rigs operating under a drilling contract, in addition to the service fee and reimbursement of direct costs, we are entitled to a gross margin bonus, as adjusted pursuant to the MMSA, and a commission. The daily service fee revenue is recognized in line with the contractual rate billed for the services provided and is reported in “Contract drilling” in our unaudited Condensed Consolidated Statements of Operations. We record the revenue relating to reimbursed expenses at the gross amount incurred and billed to the rig owner, as “Revenues related to reimbursable expenses” in our unaudited Condensed Consolidated Statements of Operations.

In March 2022, the West Auriga, one of the three managed rigs, began a one-year contract in the U.S. Gulf of Mexico (or GOM). Upon commencement of operations of the West Auriga, the MMSA for this rig was suspended and replaced by a charter agreement for the duration of the drilling contract. We have entered into the drilling contract directly with the customer and will receive and recognize revenue under the terms of the contract and have reported the revenue earned as “Contract drilling” in our unaudited Condensed Consolidated Statements of Operations. We have determined that the charter arrangement is an operating lease, and the related charter fee has been reported as lease expense within “Contract drilling, excluding depreciation” in our unaudited Condensed Consolidated Statements of Operations.

Contract Balances

The following table provides information about receivables, contract assets and contract liabilities from our contracts with customers (in thousands):


	Successor
	June 30,			December 31,
	2022			2021
Trade receivables	$	140,777		$	130,021
Current contract assets (1)		5,183			1,835
Current contract liabilities (deferred revenue) (1)		(22,442	)		(38,506	)
Noncurrent contract liabilities (deferred revenue) (1)		(4,980	)		(9,787	)

(1)

Contract assets and contract liabilities may reflect balances which have been netted together on a contract basis. Net current contract asset and liability balances are included in “Prepaid expenses and other current assets” and “Accrued liabilities,” respectively, and net noncurrent contract liability balances are included in “Other liabilities” in our unaudited Condensed Consolidated Balance Sheets.

Significant changes in the contract assets and the contract liabilities balances during the period are as follows (in thousands):


	Successor
	Net Contract
	Balances
Contract assets at January 1, 2022	$	1,835
Contract liabilities at January 1, 2022		(48,293	)
Net balance at January 1, 2022		(46,458	)
Decrease due to amortization of revenue included in the beginning contract liability balance		12,582
Decrease due to cash received, excluding amounts recognized as revenue during the period		8,104
Increase due to revenue recognized during the period but contingent on future performance		3,533
Net balance at June 30, 2022	$	(22,239	)
Contract assets at June 30, 2022	$	5,183
Contract liabilities at June 30, 2022		(27,422	)

Transaction Price Allocated to Remaining Performance Obligations

The following table reflects the specified types of revenue expected to be recognized in the future related to unsatisfied performance obligations as of June 30, 2022 (in thousands):


	For the Years Ending December 31,
	2022 (1)		2023		2024		Total
Mobilization and contract preparation revenue	$	4,462	$	6,252	$	225	$	10,939
Capital modification revenue		8,489		5,364		287		14,140
Demobilization and other deferred revenue		2,563		82		—		2,645
Total	$	15,514	$	11,698	$	512	$	27,724

(1)

Represents the six-month period beginning July 1, 2022.

The revenue included above consists of expected fixed mobilization and upgrade revenue for both wholly and partially unsatisfied performance obligations, as well as expected variable mobilization and upgrade revenue for partially unsatisfied performance obligations, which has been estimated for purposes of allocating across the entire corresponding performance obligations. The amounts are derived from the specific terms within drilling contracts that contain such provisions, and the expected timing for recognition of such revenue is based on the estimated start date and duration of each respective contract based on information known at June 30, 2022. The actual timing of recognition of such amounts may vary due to factors outside of our control. We have applied the disclosure practical expedient in FASB Accounting Standards Update (or ASU) No. 2014-09, Revenue from Contracts with Customers (Topic 606) and its related amendments, and have not included estimated variable consideration related to wholly unsatisfied performance obligations or to distinct future time increments within our contracts, including dayrate revenue.

3. Impairment of Assets

2021 Impairment. During the first quarter of 2021, we identified indicators that the carrying amounts of certain of our assets may not be recoverable and evaluated three of our drilling rigs with indicators of impairment. Based on our assumptions and analysis at that time, we determined that the carrying value of one of these rigs, for which we had concerns regarding future opportunities, was impaired (or the 2021 Impaired Rig). We estimated the fair value of the 2021 Impaired Rig using an income approach, whereby the fair value of the rig was estimated based on a calculation of the rig’s future net cash flows. These calculations utilized significant unobservable inputs, including management’s assumptions related to estimated dayrate revenue, rig utilization, estimated capital expenditures, repair and regulatory survey costs, as well as estimated proceeds that may be received on ultimate disposition of the rig. Our fair value estimate was representative of a Level 3 fair value measurement due to the significant level of estimation involved and the lack of transparency as to the inputs used. We recorded asset impairments aggregating $197.0 million for the Predecessor period from January 1, 2021 through April 23, 2021.

No asset impairments were recorded in the Successor six-month period ended June 30, 2022 or the period from April 24, 2021 through June 30, 2021.

4. Supplemental Financial Information

Unaudited Condensed Consolidated Balance Sheets Information

Accounts receivable, net of allowance for credit losses, consist of the following (in thousands):


	Successor
	June 30,			December 31,
	2022			2021
Trade receivables	$	140,777		$	130,021
Federal income tax receivables		9,320			9,278
Value added tax receivables		4,833			9,729
Related party receivables		76			66
Other		1,978			2,823
		156,984			151,917
Allowance for credit losses		(5,610	)		(5,582	)
Total	$	151,374		$	146,335

The allowance for credit losses at June 30, 2022 and December 31, 2021 represents our estimate of credit losses associated with our “Trade receivables” and “Current contract assets.” See Note 5 “Financial Instruments and Fair Value Disclosures” for a discussion of our concentrations of credit risk and allowance for credit losses.

Prepaid expenses and other current assets consist of the following (in thousands):


	Successor
	June 30,		December 31,
	2022		2021
Prepaid taxes	$	18,989	$	16,163
Deferred contract costs		13,859		7,267
Rig spare parts and supplies		8,847		3,716
Prepaid insurance		6,446		3,436
Current contract assets		5,183		1,835
Prepaid rig costs		4,673		4,048
Collateral deposits		—		17,480
Other		7,874		7,495
Total	$	65,871	$	61,440

Accrued liabilities consist of the following (in thousands):


	Successor
	June 30,		December 31,
	2022		2021
Rig operating costs	$	40,250	$	42,532
Deferred revenue		22,442		38,506
Payroll and benefits		32,074		29,268
Current operating lease liability		16,121		15,998
Contract advances		15,699		—
Shorebase and administrative costs		6,729		5,776
Personal injury and other claims		4,776		5,598
Interest payable		2,462		2,986
Accrued capital project/upgrade costs		2,234		2,219
Other		2,943		853
Total	$	145,730	$	143,736

Unaudited Condensed Consolidated Statements of Cash Flows Information

Noncash operating, investing and financing activities excluded from the unaudited Condensed Consolidated Statements of Cash Flows and other supplemental cash flow information are as follows (in thousands):


	Successor				Predecessor
			Period from		Period from
	Six Months Ended		April 24, 2021		January 1, 2021
	June 30,		through June 30,		through April 23,
	2022		2021		2021
Accrued but unpaid capital expenditures at period end	$	2,234	$	8,805	$	18,617
Accrued but unpaid debt issuance costs and arrangement fees (1)		—		7,047		7,588
Common stock withheld for payroll tax obligations (2)		139		—		—
Cash interest payments		12,514		1,346		37,593
Cash paid for reorganization items, net		—		15,809		37,566
Cash income taxes paid, net of (refunds):
Foreign		11,578		101		3,460
U.S. Federal		2,387		—		—
State		—		—		(34	)

(1)

Represents unpaid debt issuance costs related to our exit financing that were incurred and capitalized during the Predecessor period from January 1, 2021 through April 23, 2021.

(2)

Represents the cost of 17,806 shares of common stock withheld to satisfy payroll tax obligations incurred as a result of the vesting of restricted stock in the Successor six-month period ended June 30, 2022. These costs for the Successor six-month period ended June 30, 2022 are presented as a deduction from stockholders’ equity in “Treasury stock” in our unaudited Condensed Consolidated Successor Balance Sheet at June 30, 2022.

5. Financial Instruments and Fair Value Disclosures

Concentrations of Credit Risk and Allowance for Credit Losses

Our credit risk corresponds primarily to trade receivables. Since the market for our services is the offshore oil and gas industry, our customer base consists primarily of major and independent oil and gas companies, as well as government-owned oil companies. At June 30, 2022, we believe that we have potentially significant concentrations of credit risk due to the number of rigs we currently have contracted and our limited number of customers, as some of our customers have contracted for multiple rigs.

In general, before working for a customer with whom we have not had a prior business relationship and/or whose financial stability may be uncertain, we perform a credit review on that customer, including a review of its credit ratings and financial statements. Based on our credit review, we may require that the customer have a bank issue a letter of credit on its behalf, prepay for the services in advance or provide other credit enhancements. We have not required any credit enhancements by our customers or required any to pay for services in advance at June 30, 2022. We have historically used the specific identification method to identify and reserve for uncollectible accounts. The amounts reserved for uncollectible accounts in previous periods have not been significant, individually or in comparison to our total revenues. At June 30, 2022, $8.0 million in trade receivables were considered past due by 30 days or more, of which $7.5 million were fully reserved for in previous years and $0.3 million of the remaining $0.5 million were more than 90 days past due.

Pursuant to FASB ASU 2016-13 Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments and its related amendments (or collectively, CECL), we have reviewed our historical credit loss experience over a look-back period of ten years, which we deem to be representative of both up-turns and down-cycles in the offshore drilling industry. Based on this review, we developed a credit loss factor using a weighted-average ratio of our actual credit losses to revenues during the look-back period. In addition, we also considered current and future anticipated economic conditions in determining our credit loss factor, including crude oil prices and liquidity of credit markets. In applying the requirements of CECL, we segregated our trade receivables into three credit loss risk pools based on customer credit ratings, each of which represents a tier of increasing credit risk. We calculated a credit loss factor based on historical loss rate information and then applied a multiple of our credit loss factor to each of these risk pools, considering the impact of current and future economic information and the level of risk associated with these pools, to calculate our current estimate of credit losses. Trade receivables that are fully covered by allowances for credit losses are excluded from these risk pools for purposes of calculating our current estimate of credit losses.

For purposes of calculating our current estimate of credit losses at June 30, 2022 and December 31, 2021, all trade receivables were deemed to be in a single risk pool based on their credit ratings at each respective period. Our current estimate of credit losses under CECL was $0.1 million at both June 30, 2022 and December 31, 2021. Our total allowance for credit losses was $5.6 million at both June 30, 2022 and December 31, 2021. See Note 4 “Supplemental Financial Information.”

Fair Values

Fair value is defined as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. The fair value hierarchy prescribed by GAAP requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value.

There are three levels of inputs that may be used to measure fair value:


Level 1	Quoted prices for identical instruments in active markets.
Level 2	Quoted market prices for similar instruments in active markets; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations in which all significant inputs and significant value drivers are observable in active markets.
Level 3	Valuations derived from valuation techniques in which one or more significant inputs or significant value drivers are unobservable. Level 3 assets and liabilities generally include financial instruments whose value is determined using pricing models, discounted cash flow methodologies, or similar techniques, as well as instruments for which the determination of fair value requires significant management judgment or estimation or for which there is a lack of transparency as to the inputs used.

Certain of our assets and liabilities are required to be measured at fair value on a recurring basis in accordance with GAAP. In addition, certain assets and liabilities may be recorded at fair value on a nonrecurring basis. Generally, we record assets at fair value on a nonrecurring basis as a result of impairment charges.

Assets and liabilities measured at fair value are summarized below (in thousands).


	Successor
	June 30, 2022
	Fair Value Measurements Using								Total Gains
	Level 1		Level 2		Level 3		Liabilities at Fair Value		Three Months Ended (1)		Six Months Ended (1)
Recurring fair value measurements:
Liability-classified Director restricted stock units	$	617	$	—	$	—	$	617	$	120	$	241

(1)

Represents a reduction in stock compensation expense due to marking-to-market liability-classified restricted stock units granted to our non-employee directors in April 2021.


	Successor
	December 31, 2021
	Fair Value Measurements Using
	Level 1		Level 2		Level 3		Assets at Fair Value
Nonrecurring fair value measurements:
Impaired assets (1)	$	—	$	—	$	77,900	$	77,900

(1)

Represents the total book value as of December 31, 2021 of two semisubmersible rigs, which were written down to estimated fair value.

We believe that the carrying amounts of our other financial assets and liabilities (excluding our Exit Term Loans and First Lien Notes (each as defined below in Note 7 “Successor Long-Term Debt”)), which are not measured at fair value in our unaudited Condensed Consolidated Balance Sheets, approximate fair value based on the following assumptions:

•

Cash and cash equivalents and restricted cash – The carrying amounts approximate fair value because of the short maturity of these instruments.

•

Accounts receivable and accounts payable – The carrying amounts approximate fair value based on the nature of the instruments.

•

Exit RCF borrowings- The carrying amount of borrowings under our Exit RCF (as defined below in Note 7 “Successor Long-Term Debt”) approximates fair value since the variable interest rates are tied to current market rates and the applicable margins represent market rates.

Our debt is not measured at fair value on a recurring basis; however, under the GAAP fair value hierarchy, our long term debt would be considered Level 2 liabilities. The fair value of these instruments was derived using valuation specialists at June 30, 2022 and December 31, 2021.

Fair values and related carrying values of our long-term debt are shown below (in millions).


	Successor
	June 30, 2022				December 31, 2021
	Fair Value		Carrying Value		Fair Value		Carrying Value
Exit Term Loans	$	87.6	$	100.0	$	100.0	$	100.0
First Lien Notes		85.1		86.1		86.2		86.1

We have estimated the fair value amounts by using appropriate valuation methodologies and information available to management. Considerable judgment is required in developing these estimates, and accordingly, no assurance can be given that the estimated values are indicative of the amounts that would be realized in a free market exchange.

6. Drilling and Other Property and Equipment

Cost and accumulated depreciation of drilling and other property and equipment are summarized as follows (in thousands):


	Successor
	June 30,			December 31,
	2022			2021
Drilling rigs and equipment	$	1,093,694		$	1,057,739
Finance lease right of use asset		174,571			174,571
Land and buildings		9,985			9,823
Office equipment and other		2,426			2,264
Cost		1,280,676			1,244,397
Less: accumulated depreciation		(121,141	)		(68,502	)
Drilling and other property and equipment, net	$	1,159,535		$	1,175,895

7. Successor Long-Term Debt

Exit Revolving Credit Agreement

On the Effective Date, we entered into a senior secured revolving credit agreement (or the Exit Revolving Credit Agreement), which provides for a $400.0 million senior secured revolving credit facility with a $100.0 million sublimit for the issuance of letters of credit thereunder, which is scheduled to mature on April 22, 2026 (or the Exit RCF).

Borrowings under the Exit RCF may be used to finance capital expenditures, for working capital and other general corporate purposes. Availability of borrowings under the Exit RCF is subject to the satisfaction of certain conditions, including restrictions on borrowings, as provided in the Exit Revolving Credit Agreement. At June 30, 2022, we had borrowings outstanding of $123.5 million under the Exit RCF, including $3.5 million in payment-in-kind loans, and $24.1 million had been utilized for the issuance of letters of credit. The weighted average interest rate on the combined borrowings outstanding under the Exit RCF at June 30, 2022 was 5.44%.

At August 8, 2022, we had borrowings of $143.5 million outstanding under the Exit RCF and had utilized $18.0 million for the issuance of letters of credit. As of August 8, 2022, approximately $242.0 million was available for borrowings or the issuance of letters of credit under the Exit RCF, subject to its terms and conditions.

On the Effective Date, we also entered into a senior secured term loan credit agreement (or the Exit Term Loan Credit Agreement), which provides for a $100.0 million senior secured term loan credit facility scheduled to mature

on April 22, 2027, under which $100.0 million was drawn on the Effective Date (or the Exit Term Loans). The interest rate applicable to borrowings outstanding under the Exit Term Loan Credit Agreement was 7.624% at June 30, 2022.

Exit Debt

At June 30, 2022, the carrying value of the Successor long-term debt (or Exit Debt), net of unamortized discount, premium and debt issuance costs, was comprised as follows (in thousands):


	Successor
	June 30,
	2022
Borrowings under Exit RCF	$	123,478
Exit Term Loans		99,111
First Lien Notes		83,849
Total Exit Debt, net	$	306,438

The borrower under the Exit RCF and Exit Term Loan Credit Agreement (or, collectively, the Credit Facilities) is Diamond Foreign Asset Company (or DFAC) (or the Borrower) and the co-issuers of the 9.00%/11.00%/13.00% Senior Secured First Lien PIK Toggle Notes due 2027 (or the First Lien Notes) are DFAC and Diamond Finance, LLC, a wholly-owned subsidiary of DFAC that was newly formed in connection with our emergence from bankruptcy. The Credit Facilities and the First Lien Notes are unconditionally guaranteed, on a joint and several basis, by the Borrower and certain of its direct and indirect subsidiaries (or, collectively with the Borrower, the Credit Parties and each, a Credit Party) and secured by senior priority liens on substantially all of the assets of, and the equity interests in, each Credit Party, including all rigs owned by the Company as of the Effective Date or acquired thereafter and certain assets related thereto, in each case, subject to certain exceptions and limitations described in the Credit Facilities and the indenture governing the First Lien Notes.

The Exit Revolving Credit Agreement obligates the Borrower and its restricted subsidiaries to comply with certain financial maintenance covenants as defined in the Exit Revolving Credit Agreement. The Exit Revolving Credit Agreement, Exit Term Loan Credit Agreement and the indenture governing the First Lien Notes contain negative covenants that limit, among other things, the Borrower’s ability and the ability of its restricted subsidiaries to: (i) incur, assume or guarantee additional indebtedness; (ii) create, incur or assume liens; (iii) make investments; (iv) merge or consolidate with or into any other person or undergo certain other fundamental changes; (v) transfer or sell assets; (vi) pay dividends or distributions on capital stock or redeem or repurchase capital stock; (vii) enter into transactions with certain affiliates; (viii) repay, redeem or amend certain indebtedness; (ix) sell stock of its subsidiaries; or (x) enter into certain burdensome agreements. These negative covenants are subject to a number of important limitations and exceptions.

Additionally, these agreements contain other covenants, representations and warranties and events of default that are customary for a financing of this type. At June 30, 2022, we were in compliance with all covenants under the Exit Revolving Credit Agreement.

8. Commitments and Contingencies

Various claims have been filed against us in the ordinary course of business, including claims by offshore workers alleging personal injuries. With respect to each claim or exposure, we have made an assessment, in accordance with GAAP, of the probability that the resolution of the matter would ultimately result in a loss. When we determine that an unfavorable resolution of a matter is probable and such amount of loss can be determined, we record a liability for the amount of the estimated loss at the time that both of these criteria are met. Our management believes that we have recorded adequate accruals for any liabilities that may reasonably be expected to result from these claims.

Non-Income Tax and Related Claims. We have received assessments related to, or otherwise have exposure to, non-income tax items such as sales and-use tax, value-added tax, ad valorem tax, custom duties, and other similar taxes in various taxing jurisdictions. We have determined that we have a probable loss for certain of these taxes and the related penalties and interest and, accordingly, have recorded a $13.9 million and $13.7 million liability at June 30, 2022 and December 31, 2021, respectively, in "Other liabilities" in our unaudited Condensed Consolidated Balance

Sheets. We intend to defend these matters vigorously; however, the ultimate outcome of these assessments and exposures could result in additional taxes, interest and penalties for which the fully assessed amounts would have a material adverse effect on our financial condition, results of operations or cash flows.

Other Litigation. We have been named in various other claims, lawsuits or threatened actions that are incidental to the ordinary course of our business, including a claim by one of our customers in Brazil, Petróleo Brasileiro S.A. (or Petrobras), that it will seek to recover from its contractors, including us, any taxes, penalties, interest and fees that it must pay to the Brazilian tax authorities for our applicable portion of withholding taxes related to Petrobras’ charter agreements with its contractors. We intend to defend these matters vigorously; however, litigation is inherently unpredictable, and the ultimate outcome or effect of any claim, lawsuit or action cannot be predicted with certainty. As a result, there can be no assurance as to the ultimate outcome of any litigation matter. Any claims against us, whether meritorious or not, could cause us to incur significant costs and expenses and require significant amounts of management and operational time and resources. In the opinion of our management, no such pending or known threatened claims, actions or proceedings against us are expected to have a material adverse effect on our consolidated financial position, results of operations or cash flows.

Personal Injury Claims. Under our current insurance policies, we self-insure $1.0 million to $5.0 million per occurrence, depending on jurisdiction, with respect to personal injury claims not related to named windstorms in the U.S. Gulf of Mexico, which primarily result from Jones Act liability in the U.S. Gulf of Mexico. Depending on the nature, severity and frequency of claims that might arise during a policy year, if the aggregate level of claims exceed certain thresholds, we may self-insure up to $100.0 million for each subsequent occurrence. For personal injury claims arising due to named windstorms in the U.S. Gulf of Mexico, we self-insure $10.0 million for the first occurrence and, if the aggregate level of claims exceed certain thresholds, we self-insure up to $100.0 million for each subsequent occurrence, depending on the nature, severity and frequency of claims that might arise during the policy year.

The Jones Act is a federal law that permits seamen to seek compensation for certain injuries during the course of their employment on a vessel and governs the liability of vessel operators and marine employers for the work-related injury or death of an employee. We engage outside consultants to assist us in estimating our aggregate liability for personal injury claims based on our historical losses and utilizing various actuarial models. We allocate a portion of the aggregate liability to “Accrued liabilities” based on an estimate of claims expected to be paid within the next twelve months with the residual recorded as “Other liabilities.” At June 30, 2022 our estimated liability for personal injury claims was $14.2 million, of which $4.8 million and $9.4 million were recorded in “Accrued liabilities” and “Other liabilities,” respectively, in our Successor unaudited Condensed Consolidated Balance Sheets. At December 31, 2021 our estimated liability for personal injury claims was $13.5 million, of which $5.4 million and $8.1 million were recorded in “Accrued liabilities” and “Other liabilities,” respectively, in our unaudited Condensed Consolidated Balance Sheets. The eventual settlement or adjudication of these claims could differ materially from our estimated amounts due to uncertainties such as:

•

the severity and volume of personal injuries claimed;

•

the unpredictability of legal jurisdictions where the claims will ultimately be litigated;

•

inconsistent court decisions; and

•

the risks and lack of predictability inherent in personal injury litigation.

Purchase Obligations. At June 30, 2022, we had no purchase obligations for major rig upgrades or any other significant obligations, except for those related to our direct rig operations, which arise during the normal course of business.

Services Agreement. In February 2016, we entered into a ten-year agreement with a subsidiary of Baker Hughes Company (formerly named Baker Hughes, a GE company) to provide services with respect to certain blowout preventer and related well control equipment (or Well Control Equipment) on our drillships. Such services include management of maintenance, certification and reliability with respect to such equipment. Future commitments under the contractual services agreements are estimated to be approximately $24.0 million per year or an estimated $137.2 million in the aggregate over the remaining term of the agreements.

In addition, we lease Well Control Equipment for our drillships under ten-year finance leases.

Letters of Credit and Other. We were contingently liable as of June 30, 2022 in the amount of $42.7 million under certain tax, performance, supersedeas, VAT and customs bonds and letters of credit. Agreements relating to

approximately $18.6 million of customs, tax, VAT and supersedeas bonds can require collateral at any time, while the remaining agreements, aggregating $24.1 million, cannot require collateral except in events of default.

9. Income Taxes

We currently claim benefits provided under an existing tax treaty between the United Kingdom and the Republic of Senegal that allows us to claim a reduced rate of income tax withholding with respect to certain bareboat charter revenue from Senegalese sources. On May 10, 2022, The Republic of Senegal deposited its instrument of ratification for the Multilateral Convention to Implement Tax Treaty Related Measures to Prevent Base Erosion and Profit Shifting (or the MLI), which will alter certain provisions of the existing United Kingdom-Senegal Tax Treaty, effective for periods beginning on or after January 1, 2023. We are currently analyzing the impact that the Republic of Senegal’s ratification of the MLI will have on our tax position and, consequently, our consolidated financial position, results of operations and cash flows.

10. Segments and Geographic Area Analysis

We provide contract drilling services with different types of offshore drilling rigs and also provide such services in many geographic locations. However, we have aggregated these operations into one reportable segment based on the similarity of economic characteristics due to the nature of the revenue-earning process as it relates to the offshore drilling industry over the operating lives of our drilling rigs and other qualitative factors such as (i) the nature of services provided (contract drilling), (ii) similarity in operations (interchangeable rig crews and shared management and marketing, engineering, marine and maintenance support) (iii) similar regulatory environment (depending on customer and/or location), and (iv) similar contractual arrangements with customers.

Our drilling rigs are highly mobile and may be moved to other markets throughout the world in response to market conditions or customer needs. At June 30, 2022, our active drilling rigs were located offshore four countries in addition to the United States. Revenues by geographic area are presented by attributing revenues to the individual country where the services were performed.

The following tables provide information about disaggregated revenue by country (in thousands):


	Successor
	Three Months Ended June 30, 2022
	Total Contract Drilling Revenues		Revenues Related to Reimbursable Expenses		Total
United States	$	79,171	$	15,964	$	95,135
Australia		32,162		3,442		35,604
Senegal		26,704		4,103		30,807
United Kingdom		19,089		2,459		21,548
Brazil		19,753		—		19,753
Myanmar		—		2,855		2,855
Total	$	176,879	$	28,823	$	205,702


	Successor
	Six Months Ended June 30, 2022
	Total Contract Drilling Revenues		Revenues Related to Reimbursable Expenses		Total
United States	$	155,453	$	42,203	$	197,656
Australia		47,860		6,046		53,906
Senegal		53,820		5,849		59,669
United Kingdom		21,395		3,887		25,282
Brazil		39,019		—		39,019
Myanmar		9,584		6,825		16,409
Total	$	327,131	$	64,810	$	391,941


	Successor
	Period from April 24, 2021 through June 30, 2021
	Total Contract Drilling Revenues		Revenues Related to Reimbursable Expenses		Total
United States	$	50,777	$	8,723	$	59,500
Australia		23,949		5,280		29,229
United Kingdom		12,915		953		13,868
Brazil		3,224		—		3,224
Myanmar		7,168		1,922		9,090
Total	$	98,033	$	16,878	$	114,911


	Predecessor
	Period from April 1, 2021 through April 23, 2021
	Total Contract Drilling Revenues		Revenues Related to Reimbursable Expenses		Total
United States	$	19,171	$	1,055	$	20,226
Australia		5,357		1,543		6,900
United Kingdom		3,876		350		4,226
Myanmar		2,407		803		3,210
Total	$	30,811	$	3,751	$	34,562


	Predecessor
	Period from January 1, 2021 through April 23, 2021
	Total Contract Drilling Revenues		Revenues Related to Reimbursable Expenses		Total
United States	$	93,215	$	7,048	$	100,263
Australia		17,031		4,697		21,728
United Kingdom		27,967		2,300		30,267
Brazil		3,421		—		3,421
Myanmar		11,730		1,970		13,700
Total	$	153,364	$	16,015	$	169,379

ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following discussion should be read in conjunction with our unaudited condensed consolidated financial statements (including the notes thereto) included in Item 1 of Part I of this report and Item 1A, “Risk Factors” included in our Annual Report on Form 10-K for the year ended December 31, 2021, as amended by Amendment No. 1 on Form 10-K/A. References to “Diamond Offshore,” “Company,” “we,” “us” or “our” mean Diamond Offshore Drilling, Inc., a Delaware corporation, and its subsidiaries.

We provide contract drilling services to the energy industry around the globe with a fleet of 14 floater rigs (four owned drillships, eight semisubmersibles and two managed rigs). See “– Market Overview.”

Fresh Start Accounting

Upon emergence from bankruptcy on April 23, 2021 (or the Effective Date), we met the criteria for and were required to adopt fresh start accounting in accordance with Financial Accounting Standards Board Accounting Standards Codification Topic No. 852 – Reorganizations. As a result of the application of fresh start accounting and the effects of the implementation of our restructuring plan, the financial statements for the period after April 23, 2021 will not be comparable with the financial statements prior to and including April 23, 2021. References to “Successor” refer to the Company and its financial position and results of operations after the Effective Date (including December 31, 2021, June 30, 2022, the three-month and six-month periods ended June 30, 2022, and the period from April 24, 2021 through June 30, 2021). References to “Predecessor” refer to the Company and its financial position and results of operations on or before the Effective Date (including the period from January 1, 2021 through April 23, 2021). See Note 1 “General Information” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report.

Market Overview

Over the course of the second quarter of 2022, robust commodity prices continued to support offshore drilling demand, with Brent oil prices averaging approximately $113 per barrel, compared to approximately $100 per barrel in the first quarter of 2022, before settling in the $95 range as of the date of this report. In addition to robust oil prices, natural gas prices in the U.S. increased by approximately 60% in the second quarter compared to the first quarter of 2022. We believe that these improvements in commodity prices should lead to a significant increase in the cash flow generation for many of our potential customers. We expect this increase in cash flow to facilitate further capital investment by our clients, as they seek to satisfy global energy demand.

From March 2022 to July 2022, demand for floating offshore drilling rigs continued to improve, with the number of working rigs increasing by 23 rigs, or approximately 25%, based on industry reports. Some industry analysts predict that spending for offshore drilling services is likely to continue to increase in 2023 when compared to 2022. These analysts predict that the total spend for offshore drilling services will be approximately $26.7 billion in 2023, compared to $24.7 billion in 2022, representing an 8% increase year over year. Much of this demand growth is projected to be driven by growth in South America and Europe, where we currently have operations. As dayrates continue to show signs of improvement, it may become economic for other drillers to reactivate idle capacity or deliver newbuilds, limiting market upside or potentially placing downward pressure on utilization and dayrates.

Supply chain constraints and high inflation persist, driving some increases to our operating expense; however, these same forces may delay the timing, and increase the cost, of idle capacity returning to the market, thereby constraining supply in the near term.

Customer capital allocation decisions will continue to affect demand for our services. Investment mixes over time, coupled with energy demand and regulatory measures could lead to reduced demand for our services in the long term. Notwithstanding this risk, global energy demand continues to improve, and we expect increased investment in both traditional and renewable sources of energy to be required for years to come, much of which we expect to be invested in finding and producing hydrocarbons in the offshore segment.

See “– Contract Drilling Backlog” for future commitments of our rigs during the remainder of 2022 through 2024.

Contract Drilling Backlog

We believe that our contract drilling backlog provides a useful indicator of our future revenue-earning opportunities. Our contract drilling backlog, as presented below, includes only firm commitments (typically represented by signed contracts) and is calculated by multiplying the contracted operating dayrate by the firm contract period. The contract period is based on the number of stated days for fixed-term contracts or an estimated duration (in days) for contracts based on a fixed number of wells. Our calculation also assumes full utilization of our drilling equipment for the contract period (excluding scheduled shipyard and survey days); however, the amount of actual revenue earned and the actual periods during which revenues are earned may be different than the amounts and periods shown in the tables below due to various factors. Our utilization rates, which generally have approached 92-98% during contracted periods, can be adversely impacted by downtime due to various operating factors including unscheduled repairs and maintenance, weather conditions and effects of COVID-19 and related delays. Contract drilling backlog excludes revenues for mobilization, demobilization, contract preparation and customer reimbursables. Revenue is generally not earned during periods of downtime for regulatory surveys; however, certain contracts may provide for reduced revenue during the survey period. Changes in our contract drilling backlog between periods are generally a function of the performance of work on term contracts, as well as the extension or modification of existing term contracts and the execution of additional contracts. In addition, under certain circumstances, our customers may seek to terminate or renegotiate our contracts, which could adversely affect our reported backlog.

The backlog information presented below does not, nor is it intended to, align with the disclosures regarding revenue expected to be recognized in the future related to unsatisfied performance obligations, which are presented in Note 2 “Revenue from Contracts with Customers” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report. Contract drilling backlog includes only future dayrate revenue as described above, while the disclosure in Note 2 “Revenue from Contracts with Customers” excludes dayrate revenue and reflects expected future revenue for mobilization, demobilization and capital modifications to our rigs, which are related to non-distinct promises within our signed contracts. See “– Important Factors That May Impact Our Operating Results, Financial Condition or Cash Flows.”

The following table reflects our contract drilling backlog as of July 1, 2022 (and does not include any contracts signed after July 1, 2022 but prior to the date of this report), January 1, 2022 (the date reported in our Annual Report on Form 10-K for the year ended December 31, 2021), and July 1, 2021 (the date reported in our Quarterly Report on Form 10-Q for the quarter ended June 30, 2021) (in millions).


	July 1, 2022 (1)		January 1, 2022 (1)		July 1, 2021 (2)
Contract Drilling Backlog	$	995	$	1,191	$	1,073

(1)

Includes contract backlog of $91.8 million and $116.0 million at July 1, 2022 and January 1, 2022, respectively, attributable to customer drilling contracts secured for rigs managed, but not owned, by us. We entered into the drilling contracts directly with the customer and will receive and recognize revenue under the terms of the contract. Pursuant to the terms of the charter agreement with the rig owner, we will realize a gross margin equivalent to our management and marketing fee.

(2)

Contract drilling backlog as of July 1, 2021 excludes future commitment amounts totaling approximately $47.0 million payable by a customer in the form of a guarantee of gross margin to be earned on future contracts or by direct payment, pursuant to terms of an existing contract.

The following table reflects the amount of revenue related to our contract drilling backlog by year as of July 1, 2022 (in millions).


	For the Years Ending December 31,
	Total		2022 (1)		2023		2024
Contract Drilling Backlog (2)	$	995	$	394	$	456	$	145

(1)

Represents the six-month period beginning July 1, 2022.

(2)

Includes contract backlog of $76.3 million and $15.5 million in 2022 and 2023, respectively, attributable to customer drilling contracts secured for two rigs managed under the MMSA. We have entered into the drilling

contracts directly with the customer and will receive and recognize revenue under the terms of the contract. Pursuant to the terms of the charter agreement with the rig owner, we will realize a gross margin equivalent to our management and marketing fee.

The following table reflects the percentage of rig days per year committed as of July 1, 2022. The percentage of rig days committed is calculated as the ratio of total days committed under contracts, as well as scheduled shipyard, survey and mobilization days for all rigs in our fleet, to total available days (number of rigs, including cold-stacked rigs, multiplied by the number of days in a particular year).


	For the Years Ending December 31,
	2022 (1)			2023			2024
Percentage of Rig Days Committed (2)		71	%		40	%		14	%

(1)

Represents the six-month period beginning July 1, 2022.

(2)

As of July 1, 2022, includes approximately 77 and 111 rig days currently known and scheduled for contract preparation, mobilization of rigs, surveys and extended repair and maintenance projects in the remainder of 2022 and in 2023, respectively.

Important Factors That May Impact Our Operating Results, Financial Condition or Cash Flows

COVID-19 Pandemic. The COVID-19 outbreak and efforts to mitigate the spread of the virus continue to adversely impact our business as a result of risks to the safety of our personnel, as well as travel restrictions that may continue to arise, challenging the ability to move personnel, equipment, supplies and service personnel to and from our drilling rigs. In response, we have adopted COVID-19 vaccination and testing requirements, as well as other health protocols designed to ensure the safety of our offshore personnel based on the regions in which our rigs are operating. In the current environment, we have been able to modify and/or eliminate some of our initial protocols implemented after the onset of the pandemic. We incurred incremental costs of approximately $1.6 million and $2.4 million related to the COVID-19 pandemic during the Successor quarters ended June 30, 2022 and March 31, 2022, respectively. We expect to incur similar types of costs during the remainder of 2022 but cannot predict the future financial impact of our response to the COVID-19 pandemic or its duration or potential effects in this fluid environment. As such, costs realized in the future may be more than projected, perhaps by a material amount.

Regulatory Surveys and Planned Downtime. We perform certain regulatory inspections, which we refer to as a special survey, that are due every five years for most of our rigs and an intermediate survey, which is performed every two-and-one-half years, for our North Sea rigs. Our operating income is negatively impacted when we perform these required regulatory surveys due to planned downtime during the inspection period. Our operating income is also reduced by planned downtime for upgrades, contract preparation and mobilization of rigs; however, in some cases, we may be compensated for all or a portion of this downtime. During the second half of 2022, we expect to incur approximately 77 days of planned downtime, including approximately 55 days for shipyard repairs and enhancements for the Ocean Endeavor, approximately 14 days for the mobilization of the Ocean BlackHawk to Senegal and related contract preparation and customer acceptance activities and approximately eight days for the movement of rigs. During 2023, we expect to incur approximately 111 days of planned downtime, approximately 104 days for an equipment upgrade for the Ocean Apex and seven days for the completion of the Ocean Endeavor shipyard work that commenced in 2022 and demobilization of rigs. We can provide no assurance as to the exact timing and/or duration of downtime associated with regulatory inspections, repairs, contract preparation, rig mobilizations and other shipyard projects. See “ – Contract Drilling Backlog.”

Physical Damage and Marine Liability Insurance. We are self-insured for physical damage to rigs and equipment caused by named windstorms in the U.S. Gulf of Mexico, as defined by the relevant insurance policy. If a named windstorm in the U.S. Gulf of Mexico causes significant damage to our rigs or equipment, it could have a material adverse effect on our financial condition, results of operations and cash flows. Under our current insurance policy, we carry physical damage insurance for certain losses other than those caused by named windstorms in the U.S. Gulf of Mexico for which our deductible for physical damage is $10.0 million per occurrence. In addition, we currently carry loss-of-hire insurance on certain rigs to cover lost cash flow when a rig is damaged (other than when caused by named windstorms in the U.S. Gulf of Mexico) but have not purchased loss-of-hire insurance for our entire fleet.

In addition, we carry marine liability insurance covering certain legal liabilities, including coverage for certain personal injury claims, collisions, and wreck removals, and generally covering liabilities arising out of or relating to pollution and/or environmental risk. We believe that the policy limit for our marine liability insurance is within the range that is customary for companies of our size in the offshore drilling industry and is appropriate for our business. Under these marine liability policies, we self-insure $1.0 million to $5.0 million per occurrence, depending on jurisdiction, but up to $25.0 million for liabilities arising out of named windstorms in the U.S. Gulf of Mexico. Depending on the nature, severity, and frequency of claims that might arise during the policy year, if the aggregate level of claims exceed certain thresholds, we may self-insure up to $100.0 million for each subsequent occurrence.

Critical Accounting Policies

Our significant accounting policies are discussed in Note 1 “General Information” of our notes to the audited consolidated financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2021.

Results of Operations

We have elected to present a comparison of our results of operations for the current quarter with that of the immediately preceding quarter, as permitted under Item 303(c)(2)(ii) of Regulation S-K. We believe this comparison is more useful in identifying business trends and provides a more meaningful analysis of our business as our results are largely driven by market changes rather than seasonal business activity. We continue to present the required comparison of current year-to-date results with the same period of the prior year.

Our operating results for contract drilling services are dependent on three primary metrics or key performance indicators: revenue-earning (or R-E) days, rig utilization and average daily revenue. We believe that R-E days provide a comparative measurement of the activity level of our fleet, rig utilization is an indicator of our ability to secure work for and the operational efficiency of our fleet and average daily revenue provides a comparative measure for our revenue-earning performance. We utilize these performance indicators in the review of our business and operating results and believe these are useful metrics for investors to utilize in evaluating our performance. The tables presented below include these three key performance indicators and other comparative data relating to our revenues and operating expenses for the respective periods (in thousands, except days, daily amounts and percentages) for the Successor six-month period ended June 30, 2022, three-month periods ended June 30, 2022 and March 31, 2022 and the period from April 24, 2021 through June 30, 2021 and the Predecessor period from January 1, 2021 through April 23, 2021.

Results for the Three-Month Periods Ended June 30, 2022 and March 31, 2022


	Successor
	Three Months Ended June 30,			Three Months Ended March 31,
	2022			2022
REVENUE-EARNING DAYS (1)		776			668
UTILIZATION (2)		57	%		53	%
AVERAGE DAILY REVENUE (3)	$	227,800		$	224,900

CONTRACT DRILLING REVENUE	$	176,879		$	150,252
REVENUE RELATED TO REIMBURSABLE EXPENSES		28,823			35,987
TOTAL REVENUES	$	205,702		$	186,239
CONTRACT DRILLING EXPENSE, EXCLUDING DEPRECIATION	$	142,150		$	144,902
REIMBURSABLE EXPENSES	$	28,554		$	35,613
OPERATING INCOME (LOSS)
Contract drilling services, net	$	34,729		$	5,350
Reimbursable expenses, net		269			374
Depreciation		(25,693	)		(26,952	)
General and administrative expense		(19,753	)		(16,732	)
Gain on disposition of assets		685			4,044
Total Operating Loss	$	(9,763	)	$	(33,916	)
Other income (expense):
Interest income		—			1
Interest expense, net of amounts capitalized		(10,103	)		(8,325	)
Foreign currency transaction gain (loss)		1,607			(2,129	)
Other, net		(47	)		1,362
Loss before income tax (expense) benefit		(18,306	)		(43,007	)
Income tax (expense) benefit		(3,623	)		8,653
NET LOSS	$	(21,929	)	$	(34,354	)

(1)

An R-E day is defined as a 24-hour period during which a rig earns a dayrate after commencement of operations and excludes mobilization, demobilization and contract preparation days.

(2)

Utilization is calculated as the ratio of total R-E days divided by the total calendar days in the period for all rigs in our fleet (including managed and cold-stacked rigs).

(3)

Average daily revenue is defined as total contract drilling revenue for all of the rigs in our fleet (including managed rigs) per R-E day.

Three Months Ended June 30, 2022 Compared to Three Months Ended March 31, 2022

Contract Drilling Revenue. Contract drilling revenue increased $26.6 million during the three months ended June 30, 2022, compared to the three months ended March 31, 2022, primarily due to a 108-day increase in R-E days ($24.3 million), in addition to higher average daily revenue earned ($2.3 million). The increase in R-E days was primarily due to fewer downtime days during the second quarter of 2022 for the Ocean Endeavor and Ocean Patriot, both of which were out of service for repairs in the first quarter of 2022 (124 additional R-E days), and the Ocean Apex, which was warm stacked during the first quarter 2022 but commenced its current contract in May 2022 (53 additional R-E days). R-E days also reflect operation of the West Auriga, a rig managed under the MMSA, under a one-year contract in the GOM that commenced in March 2022 and other incremental R-E days (46 additional R-E days). The increase in R-E days was partially offset by incremental downtime associated with the cold stacking of the Ocean Monarch after completion of its contract in Myanmar (82 fewer days) and mobilization of the Ocean BlackHawk to Senegal (39 fewer days).

Revenue Related to Reimbursable Expenses. During the second quarter of 2022 and first quarter of 2022, we recognized gross reimbursable revenue and expenses of $11.6 million and $23.2 million, respectively, pursuant to the MMSA.

Contract Drilling Expense, Excluding Depreciation. Contract drilling expense, excluding depreciation was relatively unchanged for the three months ended June 30, 2022, compared to the three months ended March 31, 2022, decreasing a net $2.8 million. The decrease in contract drilling expense reflects lower repair, maintenance and mobilization costs ($7.2 million), primarily for the Ocean Endeavor and Ocean Patriot, and the absence of expenses related to the Ocean Valor ($2.9 million), which was sold in February 2022. The net decrease in contract drilling expense was partially offset by incremental operating expenses for the West Auriga ($7.3 million).

General and Administrative Expense. General and administrative expense for the second quarter of 2022 increased $3.0 million compared to the first quarter of 2022, and included $4.0 million in incremental compensation expense associated with the recognition of expense related to certain performance-based restricted stock awards granted in May 2021. Vesting of these awards is contingent upon the occurrence of certain conditions or events that were not deemed probable at the time of the award, and no expense related to these awards had been recognized previously. During the second quarter of 2022, certain of the market conditions were deemed to be satisfied, prompting the recognition of expense related to a portion of these restricted shares.

Gain on Disposition of Assets. During the first quarter of 2022, we sold the Ocean Valor for aggregate proceeds of approximately $6.6 million and recognized a net gain on the transaction of $4.2 million.

Income Tax Benefit. We estimate our annual effective tax rate (or AETR) for continuing operations in recording our interim quarterly income tax provision considering the various jurisdictions in which we operate. Discrete tax adjustments are excluded from the computation of the AETR and recorded in the quarter in which they occur.

We recorded net income tax expense of $3.6 million (negative 19.8% effective tax rate) for the three months ended June 30, 2022. For the three months ended March 31, 2022, we recorded a net income tax benefit of $8.7 million (20.1% effective tax rate). The lower effective tax rate for the second quarter of 2022, reflects our domestic and international jurisdictional mix of estimated pre-tax income and losses for the period and the fact that we have not recognized an income tax benefit for losses in certain jurisdictions due to a valuation allowance, while recognizing income tax expense for jurisdictions with forecasted pre-tax income. Additionally, the variance in the effective tax rate reflects a $4.7 million benefit recognized in the first quarter of 2022 for remeasurement of unrecognized tax benefits due to expiring statutes of limitation and strengthening of the U.S. dollar relative to foreign currencies.

Results for the Successor Six-Month Period Ended June 30, 2022 and the Period from April 24, 2021 through June 30, 2021 and for the Predecessor Period from January 1, 2021 through April 23, 2021.


	Successor						Predecessor
	Six Months Ended			Period from April 24, 2021 through			Period From January 1, 2021 through
	June 30, 2022			June 30, 2021			April, 23, 2021
REVENUE-EARNING DAYS		1,445			498			724
UTILIZATION		55	%		56	%		53	%
AVERAGE DAILY REVENUE	$	226,000		$	197,000		$	211,800

CONTRACT DRILLING REVENUE	$	327,131		$	98,033		$	153,364
REVENUE RELATED TO REIMBURSABLE EXPENSES		64,810			16,878			16,015
TOTAL REVENUES	$	391,941		$	114,911		$	169,379
CONTRACT DRILLING EXPENSE, EXCLUDING DEPRECIATION	$	287,052		$	90,711		$	181,626
REIMBURSABLE EXPENSES	$	64,167		$	16,572		$	15,477
OPERATING INCOME (LOSS)
Contract drilling services, net	$	40,079		$	7,322		$	(28,262	)
Reimbursable expenses, net		643			306			538
Depreciation		(52,645	)		(18,735	)		(92,758	)
General and administrative expense		(36,485	)		(16,217	)		(15,036	)
Impairment of assets		—			—			(197,027	)
Gain on disposition of assets		4,729			176			5,486
Total Operating Loss	$	(43,679	)	$	(27,148	)	$	(327,059	)
Other income (expense):
Interest income		1			1			30
Interest expense, net of amounts capitalized		(18,428	)		(7,097	)		(34,827	)
Foreign currency transaction (loss) gain		(522	)		(914	)		(172	)
Reorganization items, net		—			(5,538	)		(1,639,763	)
Other, net		1,315			10,706			398
Loss before income tax benefit (expense)		(61,313	)		(29,990	)		(2,001,393	)
Income tax benefit (expense)		5,030			(17,303	)		39,404
NET LOSS	$	(56,283	)	$	(47,293	)	$	(1,961,989	)

Six Months Ended June 30, 2022 (Successor) Compared to the Period from April 24, 2021 through June 30, 2021 (Successor) and the Period from January 1, 2021 through April 23, 2021 (Predecessor)

Contract Drilling Revenue. During the Successor six-month period ended June 30, 2022, we earned contract drilling revenue of $327.1 million attributable to 1,445 R-E days and average daily revenue of $226,400. Total utilization for the period was 55%, reflecting downtime for the Ocean Endeavor and Ocean Patriot for inspections, repairs and associated mobilization (200 days), planned downtime related to contract preparation activities for the Ocean Apex and Ocean BlackHawk (160 days) and cold-stacked rigs (460 days).

The increase in average daily revenue for the Successor six-month period ended June 30, 2022, compared to the Successor period from April 24, 2021 to June 30, 2021, was primarily due to the amortization of capital upgrade revenue for the Ocean BlackLion and a rate increase for the Ocean Onyx compared to the Successor period in 2021. Additionally, the Ocean BlackRhino was on contract in Senegal during the 2022 period, but in a shipyard during 2021 awaiting contract commencement.

During the Successor period from April 24, 2021 to June 30, 2021, we earned contract drilling revenue of $98.0 million attributable to 498 R-E days and average daily revenue of $197,000. Total utilization for the period was 56%, reflecting downtime for the Ocean BlackRhino and Ocean Courage for contract preparation work (122 days) and the

Ocean Endeavor for repairs and inspection (35 days). The decline in average daily revenue reflects reduced amortization of deferred revenue due to the write off of such balances at the Effective Date in connection with fresh start accounting. Prior to fresh start accounting, such amounts would have been amortized into income over the respective contract terms.

During the Predecessor period from January 1, 2021 through April 23, 2021, we earned contract drilling revenue of $153.4 million attributable to 724 R-E days and average daily revenue of $211,800. Total utilization for the period was 53%. Six of our then contracted rigs operated at nearly full utilization for the period, while three rigs were preparing for upcoming contracts throughout most of the period. The Ocean Onyx commenced a new contract in February 2021 after its reactivation and contributed 61 R-E days to the period.

Contract Drilling Expense, Excluding Depreciation. During the Successor six-month period ended June 30, 2022, contract drilling expense, excluding depreciation totaled $287.1 million, primarily comprised of payroll and benefits cost ($140.4 million), repairs, maintenance and inspection ($83.4 million), equipment rentals ($21.5 million), shorebase cost and overhead ($26.4 million), moving cost ($11.3 million) and other ($4.1 million). Increased payroll and benefits costs are partially attributable to a rig retention bonus implemented for certain of our drilling rigs in early 2022.

During the Successor period from April 24, 2021 through June 30, 2021 (a 68-day period), contract drilling expense, excluding depreciation totaled $90.7 million, comprised primarily of payroll and employees cost ($45.1 million), repairs, maintenance and inspection ($26.2 million), equipment rentals ($6.7 million), shorebase cost and overhead ($8.0 million), moving cost ($3.4 million) and other ($1.3 million).

During the Predecessor period from January 1, 2021 through April 23, 2021 (a 113-day period), contract drilling expense, excluding depreciation totaled $181.6 million and was primarily comprised of payroll and employees cost ($73.5 million), repairs, maintenance and inspection ($39.6 million), equipment rentals ($24.4 million), shorebase cost and overhead ($20.8 million), moving cost ($12.8 million) and other ($10.5 million).

Depreciation Expense. Depreciation expense for the Successor six-month period ended June 30, 2022 and the period from April 24, 2021 through June 30, 2021 and the Predecessor period from January 1, 2021 through April 23, 2021 was $52.6 million, $18.7 million and $92.8 million, respectively. The decline in depreciation expense since the Effective Date was primarily due to the reduction in depreciable value of our rigs and equipment as a result of the fair value remeasurement of rigs and equipment in connection with the application of fresh start accounting and asset impairments recognized in the fourth quarter of 2021.

General and Administrative Expense. General and administrative expense for the Successor six-month period ended June 30, 2022 and the period from April 24 through June 30,2021 and Predecessor period from January 1, 2021 through April 23, 2021 was $36.5 million, $16.2 million and $15.0 million, respectively. Expenses incurred during Successor six months ended June 30, 2022 included payroll and benefits ($20.4 million), legal and professional fees ($11.6 million) and other ($4.5 million). For the Successor period from April 24, 2021 through June 30, 2021, general and administrative expense included payroll and benefits ($11.2 million), professional and legal fees ($3.4 million) and other ($1.6 million). Expenses incurred during the Predecessor period from January 1, 2021 through April 23, 2021 included payroll and benefits costs ($9.9 million), professional and legal fees ($3.6 million) and other ($1.5 million). Payroll and benefits costs for the Successor six-month period ended June 30, 2022 included $4.0 million in incremental compensation expense associated with certain performance-based restricted stock awards granted in 2021.

Impairment of Assets. During the Predecessor period from January 1, 2021 through April 23, 2021, we recognized an impairment charge of $197.0 million to write down the carrying value of one of our rigs with indicators of impairment due to concerns at that time over future opportunities for the rig. See Note 3 “Impairment of Assets” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report.

Interest Expense. Interest expense for the Successor six-month period ended June 30, 2022 included interest cost related to our exit financing ($12.1 million), imputed interest expense related to our equipment finance leases ($5.3 million) and other ($1.0 million). Interest expense for the Successor period from April 24, 2021 through June 30, 2021 included interest on exit financing ($4.6 million), interest on equipment finance leases ($2.2 million) and other ($0.3 million).

Upon filing for bankruptcy protection on April 26, 2020, we ceased accruing interest expense on our then outstanding long-term indebtedness and borrowings outstanding under our previous credit facility. However, due to provisions in our plan of reorganization, we resumed recognizing interest on our outstanding borrowings under the previous credit facility and accrued interest expense of $34.8 million for the Predecessor period from January 1, 2021 to April 23, 2021, inclusive of a $23.4 million catch-up adjustment for the period from April 26, 2020 to December 31, 2020.

Income Tax Benefit. We recorded a net income tax benefit of $5.0 million (8.2% effective tax rate) for the Successor six-month period ended June 30, 2022, as compared with income tax expense of $17.3 million (negative 57.7% effective tax rate) for the Successor period from April 24, 2021 to June 30, 2021. The variance in the effective tax rates reflects the change in the domestic and international mix of our pre-tax income and loss and between the periods.

For the Predecessor period from January 1, 2021 to April 23, 2021, we recorded an income tax benefit of $39.4 million (1.9% effective tax rate), which reflects certain consequences of the Predecessor’s bankruptcy filing. The relatively larger income tax benefit for the six months ended June 30, 2022, reflects changes in the domestic and international jurisdictional mix of our pre-tax income and loss, which are consequences, in part, of realigning substantially all of our assets and operations under a foreign subsidiary in the April 2021.

Liquidity and Capital Resources

We have available a senior secured revolving credit agreement (or the Exit Revolving Credit Agreement) that provides for a $400.0 million senior secured revolving credit facility with a $100.0 million sublimit for the issuance of letters of credit thereunder (or the Exit RCF). At August 8, 2022, we had borrowings of $143.5 million outstanding under the Exit RCF and had utilized $18.0 million for the issuance of letters of credit. As of August 8, 2022, approximately $242.0 million was available for borrowings or the issuance of letters of credit under the Exit RCF.

However, the availability of borrowings and letters of credit under the Exit RCF is subject to the satisfaction of certain conditions as specified in the Exit Revolving Credit Agreement, including restrictions on borrowings.

In addition, we have approximately $39.7 million in the form of delayed draw note commitments that may be issued as additional First Lien Notes (as defined below), none which had been issued as of August 8, 2022.

We have also historically relied on our cash flows from operations and cash reserves to meet our liquidity needs, which primarily include funding of our working capital requirements and capital expenditures, as well as the servicing of our debt repayments and interest payments. As of August 8, 2022, all of our rigs, excluding managed rigs, are owned and operated, directly or indirectly, by Diamond Foreign Asset Company (or DFAC). Our management has determined that we will permanently reinvest foreign earnings, which restricts the ability to utilize cash flows of DFAC on a company-wide basis. To the extent possible, we expect to utilize the operating cash flows and cash reserves of DFAC and the operating cash flows available to and cash reserves of Diamond Offshore Drilling, Inc. to meet each respective entity's working capital requirements and capital commitments.

As of July 1, 2022, our contractual backlog was approximately $1.0 billion. At June 30, 2022, we had cash available for current operations of $57.6 million, including $14.7 million that is subject to restrictions pursuant to the MMSA.

Sources and Uses of Cash

Historical Cash Flow from Operations

For the Successor six-month period ended June 30, 2022, our operating activities used cash of $10.8 million. Cash expenditures for contract drilling, shorebase support, and general and administrative costs ($392.7 million) and cash income taxes paid, net of refunds ($14.0 million), were partially offset by cash receipts from contract drilling services ($378.4 million) during the six-month period. Collateral deposits aggregating $17.5 million were exchanged for letters of credit drawn under the Exit RCF, positively impacting cash flow but with a neutral effect on total liquidity.

Cash outlays for capital expenditures during the first six months of 2022 aggregated $32.4 million (including capital outlays for the Ocean Endeavor and Ocean Patriot shipyard work). We also paid $7.7 million in finance lease obligations during the period. Asset sales, including the sale of the Ocean Valor, generated cash proceeds of $5.8 million, and we borrowed $40.0 million under the Exit RCF during the first six months of 2022.

For the Successor period from April 24, 2021 through June 30, 2021, our operating activities used $66.0 million. Cash expenditures for contract drilling, shorebase support and general and administrative costs ($134.4 million) and payments to professionals in connection with our bankruptcy cases ($15.8 million) more than offset cash receipts for contract drilling services ($84.2 million) for the period. In addition, cash outlays for capital expenditures during the period aggregated $24.0 million, and we borrowed an incremental $30.0 million under the Exit RCF.

For the Predecessor period from January 1, 2021 through April 23, 2021, our operating activities used $100.1 million. Cash expenditures for contract drilling, shorebase support and general and administrative costs ($243.9 million), payments to professionals in connection with our bankruptcy cases ($37.6 million), and net cash income taxes paid ($3.4 million) offset cash receipts for contract drilling services ($181.4 million) for the period. Cash outlays for capital expenditures aggregated $49.1 million for the period.

As set forth in our plan of reorganization, on the Effective Date, we settled $242.0 million outstanding under our previous credit facility in cash and issued $75.0 million of First Lien Notes.

Upgrades and Other Capital Expenditures

As of the date of this report, we expect cash capital expenditures for 2022 to be approximately $75 million to $80 million pursuant to our capital maintenance programs.

Other Obligations

As of June 30, 2022, the total net unrecognized tax benefits related to uncertain tax positions that could result in a future cash payment was $43.6 million. Due to the high degree of uncertainty regarding the timing of future cash outflows associated with the liabilities recognized in these balances, we are unable to make reasonably reliable estimates of the period of cash settlement with the respective taxing authorities.

Other Commercial Commitments - Letters of Credit

See Note 8 “Commitments and Contingencies” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report for a discussion of certain of our other commercial commitments.

Forward-Looking Statements

We or our representatives may, from time to time, either in this report, in periodic press releases or otherwise, make or incorporate by reference certain written or oral statements that are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (or the Securities Act) and Section 21E of the Securities Exchange Act of 1934, as amended (or the Exchange Act). All statements other than statements of historical fact are, or may be deemed to be, forward-looking statements. Forward-looking statements include, without limitation, any statement that may project, indicate or imply future results, events, performance or achievements, and may contain or be identified by the words “expect,” “intend,” “plan,” “predict,” “anticipate,” “estimate,” “believe,” “should,” “could,” “would,” “may,” “might,” “will,” “will be,” “will continue,” “will likely result,” “project,” “forecast,” “budget” and similar expressions. In addition, any statement concerning future financial performance (including, without limitation, future revenues, earnings or growth rates), ongoing business strategies or prospects, and possible actions taken by or against us, which may be provided by management, are also forward-looking statements as so defined. Statements made by us in this report that contain forward-looking statements may include, but are not limited to, information concerning our possible or assumed future results of operations and statements about the following subjects:

•

the effects of our former bankruptcy proceedings on our operations, including our relationships with employees, regulatory authorities, customers, suppliers, banks, insurance companies and other third parties, and agreements;

•

market conditions and the effect of such conditions on our future results of operations;

•

sources and uses of and requirements for financial resources and sources of liquidity;

•

customer spending programs;

•

business plans or financial condition of our customers, including with respect to or as a result of the COVID-19 pandemic;

•

duration and impacts of the COVID-19 pandemic, including new variants of the virus, lockdowns, re-openings and any other related actions taken by businesses and governments the offshore drilling industry and on our business, operations, supply chain and personnel, financial condition, results of operations, cash flows and liquidity;

•

expectations regarding our plans and strategies, including plans, effects and other matters relating to the COVID-19 pandemic and any new variants;

•

contractual obligations and future contract negotiations;

•

the transition to renewable energy sources and other alternative forms of energy;

•

interest rate and foreign exchange risk and the transition away from LIBOR;

•

operations outside the United States;

•

geopolitical events and risks including Russia’s invasion of Ukraine and related sanctions;

•

business strategy;

•

growth opportunities;

•

competitive position including, without limitation, competitive rigs entering the market;

•

expected financial position and liquidity;

•

cash flows and contract backlog;

•

idling drilling rigs or reactivating stacked rigs;

•

future amounts payable by a customer in the form of a guarantee of gross margin to be earned on future contracts or by direct payment, pursuant to terms of an existing contract, including the timing of such payments;

•

outcomes of litigation and legal proceedings;

•

financing plans;

•

market outlook;

•

commodity prices;

•

economic trends or developments with respect to inflation or interest rates;

•

tax planning;

•

changes in tax laws and policies or adverse outcomes resulting from examination of our tax returns;

•

debt levels and the impact of changes in the credit markets;

•

budgets for capital and other expenditures;

•

contractual obligations related to our Well Control Equipment services agreement and potential exercise of the purchase option at the end of the original lease term;

•

the MMSA with an offshore drilling company and future management and marketing services thereunder;

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timing and duration of required regulatory inspections for our drilling rigs and other planned downtime;

•

process and timing for acquiring regulatory permits and approvals for our drilling operations;

•

timing and cost of completion of capital projects;

•

delivery dates and drilling contracts related to capital projects;

•

plans and objectives of management;

•

scrapping retired rigs;

•

asset impairments and impairment evaluations;

•

assets held for sale;

•

our internal controls and internal control over financial reporting;

•

performance of contracts;

•

compliance with applicable laws; and

•

availability, limits and adequacy of insurance or indemnification.

These types of statements are based on current expectations about future events and inherently are subject to a variety of assumptions, risks and uncertainties, many of which are beyond our control, that could cause actual results to differ materially from those expected, projected or expressed in forward-looking statements. These risks and uncertainties include, among others, those described or referenced in Item 1A, “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2021, as amended by Amendment No. 1 on Form 10-K/A.

The risks and uncertainties referenced above are not exhaustive. Other sections of this report and our other filings with the Securities and Exchange Commission include additional factors that could adversely affect our business,

results of operations and financial performance. Given these risks and uncertainties, investors should not place undue reliance on forward-looking statements. Forward-looking statements included in this report speak only as of the date of this report. We expressly disclaim any obligation or undertaking to release publicly any updates or revisions to any forward-looking statement to reflect any change in our expectations or beliefs with regard to the statement or any change in events, conditions or circumstances on which any forward-looking statement is based. In addition, in certain places in this report, we may refer to reports published by third parties that purport to describe trends or developments in energy production or drilling and exploration activity. While we believe that these reports are reliable, we have not independently verified the information included in such reports. We specifically disclaim any responsibility for the accuracy and completeness of such information and undertake no obligation to update such information.

ITEM 3. Quantitative and Qualitative Disclosures About Market Risk.

The information included in this Item 3 constitutes “forward-looking statements” for purposes of the statutory safe harbor provided in Section 27A of the Securities Act and Section 21E of the Exchange Act. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Forward-Looking Statements” in Item 2 of Part I of this report.

Interest Rate Risk. We have exposure to interest rate risk on our debt instruments arising from changes in the level or volatility of interest rates. As of June 30, 2022, our variable interest rate debt included $123.5 million of outstanding borrowings under the Exit RCF, $24.1 million for the issuance of letters of credit under the Exit RCF and $100.0 million outstanding under our senior secured term loan agreement we entered into on the Effective Date. At this level of variable-rate debt, the impact of a 100-basis point increase in market interest rates would not have a material effect (estimated $2.5 million increase in interest expense on an annualized basis). Our 9.00%/11.00%/13.00% Senior Secured First Lien PIK Toggle Notes due 2027 (or the First Lien Notes) have been issued at fixed rates, and as such, interest expense would not be impacted by interest rate shifts.

There were no other material changes in our market risk components for the six months ended June 30, 2022. See “Quantitative and Qualitative Disclosures About Market Risk” included in Item 7A of our Annual Report on Form 10-K for the year ended December 31, 2021, as amended by Amendment No. 1 on Form 10-K/A, for further information.

ITEM 4. Controls and Procedures.

We maintain a system of disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in reports that we file or submit under the federal securities laws, including this report, is recorded, processed, summarized and reported on a timely basis. These disclosure controls and procedures include controls and procedures designed to ensure that information required to be disclosed by us under the federal securities laws is accumulated and communicated to our management on a timely basis to allow decisions regarding required disclosure.

Our Chief Executive Officer (or CEO) and Chief Financial Officer (or CFO) participated in an evaluation by our management of the effectiveness of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of June 30, 2022. Based on their participation in that evaluation, our CEO and CFO concluded that our disclosure controls and procedures were effective as of June 30, 2022.

There were no changes in our internal control over financial reporting identified in connection with the foregoing evaluation that occurred during our second fiscal quarter of 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.

Information related to certain legal proceedings is included in Note 8 “Commitments and Contingencies” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report, which is incorporated herein by reference.

ITEM 1A. Risk Factors.

Our Annual Report on Form 10-K for the year ended December 31, 2021, as amended by Amendment No. 1 on Form 10-K/A, includes a detailed discussion of certain material risk factors facing the Company. The risk factors included under Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2021, as amended by Amendment No. 1 on Form 10-K/A, are incorporated herein by reference. No material changes have been made to such risk factors as of June 30, 2022.

ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds.

Items 2(a) and 2(b) are not applicable.

(c) During the three months ended June 30, 2022, in connection with the vesting of shares of restricted stock held by our Chief Executive Officer, which were awarded under an equity incentive compensation plan, we acquired shares of our common stock in satisfaction of tax withholding obligations that were incurred in connection with such vesting. The date of acquisition, number of shares and average effective acquisition price per share were as follows:

Issuer Purchases of Equity Securities


Period	Total Number of Shares Acquired		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Number of Shares that May Yet Be Purchased Under the Plans or Programs
April 1, 2022 through April 30, 2022		—		—	N/A	N/A
May 1, 2022 through May 31, 2022		—		—	N/A	N/A
June 1, 2022 through June 30, 2022		17,806	$	7.79	N/A	N/A
Total		17,806	$	7.79	N/A	N/A

ITEM 6. Exhibits.


Exhibit No.		Description of Exhibit

3.1		Third Amended and Restated Certificate of Incorporation of Diamond Offshore Drilling, Inc. (incorporated by reference to Exhibit 3.1 to our Current Report on Form 8-K filed on April 29, 2021).

3.2		Second Amended and Restated Bylaws of Diamond Offshore Drilling, Inc. (incorporated by reference to Exhibit 3.2 to our Current Report on Form 8-K filed on April 29, 2021).

10.1		Specimen Time-Vesting Restricted Stock Unit Award Agreement (incorporated by reference to Exhibit 10.1 to our Current Report on Form 8-K filed on May 11, 2022).

10.2		Specimen Executive Performance-Vesting Restricted Stock Unit Award Agreement (incorporated by reference to Exhibit 10.2 to our Current Report on Form 8-K filed on May 11, 2022).

31.1*		Rule 13a-14(a) Certification of the Chief Executive Officer.

31.2*		Rule 13a-14(a) Certification of the Chief Financial Officer.

32.1*		Section 1350 Certification of the Chief Executive Officer and Chief Financial Officer.

101.INS*		Inline 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 Calculation Linkbase Document.

101.LAB*		Inline XBRL Taxonomy Label Linkbase Document.

101.PRE*		Inline XBRL Presentation Linkbase Document.

101.DEF*		Inline XBRL Definition Linkbase Document.

104*		The cover page of our Quarterly Report on Form 10-Q for the quarter ended June 30, 2022, formatted in Inline XBRL (included with the Exhibit 101 attachments).

* Filed or 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.


	DIAMOND OFFSHORE DRILLING, INC.
	(Registrant)

Date August 10, 2022	By:	/s/ Dominic A. Savarino
		Dominic A. Savarino
		Senior Vice President and Chief Financial Officer