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~~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.

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

As of October ~~25, 2019~~29, 2020 Common stock, $0.01 par value per share ~~137,694,313~~138,054,311 shares

	September 30,			December 31,			September 30,			December 31,
	2019			2018			2020			2019
ASSETS
Current assets:
Cash and cash equivalents	$	209,132		$	154,073		$	422,701		$	156,281
Marketable securities		—			299,849
Accounts receivable, net of allowance for bad debts		237,621			168,620
Restricted cash								25,692			—
Accounts receivable								144,257			256,315
Less: allowance for credit losses								(5,633	)		(5,459	)
Accounts receivable, net								138,624			250,856
Prepaid expenses and other current assets		66,669			163,396			63,269			68,658
Asset held for sale		1,000			—
Assets held for sale								2,000			1,000
Total current assets		514,422			785,938			652,286			476,795
Drilling and other property and equipment, net of
accumulated depreciation		5,150,876			5,184,222			4,243,106			5,152,828
Other assets		205,736			65,534			206,481			204,421
Total assets	$	5,871,034		$	6,035,694		$	5,101,873		$	5,834,044
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	68,760		$	43,933		$	31,980		$	68,586
Accrued liabilities		190,204			172,228			127,516			210,780
Taxes payable		20,242			20,685			28,359			23,228
Total current liabilities		279,206			236,846			187,855			302,594
Long-term debt		1,975,275			1,973,922			—			1,975,741
Deferred tax liability		54,119			104,380			30,614			47,528
Other liabilities		257,110			135,893			97,645			275,971
Total liabilities		2,565,710			2,451,041
Commitments and contingencies (Note 8)
Commitments and contingencies (Note 10)
Total liabilities not subject to compromise								316,114			2,601,834
Liabilities subject to compromise								2,653,655			—
Stockholders’ equity:
Preferred stock (par value $0.01, 25,000,000 shares authorized, NaN issued and outstanding)		—			—			—			—
Common stock (par value $0.01, 500,000,000 shares authorized; 144,769,078 shares issued and 137,694,313 shares outstanding at September 30, 2019; 144,383,662 shares issued and 137,438,353 shares outstanding at December 31, 2018)		1,448			1,444
Common stock (par value $0.01, 500,000,000 shares authorized; 145,263,865 shares issued and 138,054,311 shares outstanding at September 30, 2020; 144,781,766 shares issued and 137,703,910 shares outstanding at December 31, 2019)								1,453			1,448
Additional paid-in capital		2,022,672			2,018,143			2,029,979			2,024,347
Retained earnings		1,486,971			1,769,415			306,835			1,412,201
Accumulated other comprehensive (loss) gain		(16	)		21
Treasury stock, at cost (7,074,765 and 6,945,309 shares of common stock at September 30, 2019 and December 31, 2018, respectively)		(205,751	)		(204,370	)
Accumulated other comprehensive loss								-			(18	)
Treasury stock, at cost (7,209,554 and 7,077,856 shares of common stock at September 30, 2020 and December 31, 2019, respectively)								(206,163	)		(205,768	)
Total stockholders’ equity		3,305,324			3,584,653			2,132,104			3,232,210
Total liabilities and stockholders’ equity	$	5,871,034		$	6,035,694		$	5,101,873		$	5,834,044

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

	Three Months Ended						Nine Months Ended						Three Months Ended						Nine Months Ended
	September 30,						September 30,						September 30,						September 30,
	2019			2018			2019			2018			2020			2019			2020			2019
Revenues:
Contract drilling	$	242,315		$	280,691		$	676,284		$	833,970		$	129,345		$	242,315		$	535,848		$	676,284
Revenues related to reimbursable expenses		11,705			5,631			27,984			16,723			8,912			11,705			29,782			27,984
Total revenues		254,020			286,322			704,268			850,693			138,257			254,020			565,630			704,268
Operating expenses:
Contract drilling, excluding depreciation		201,568			188,456			593,779			562,466			130,921			201,568			481,376			593,779
Reimbursable expenses		11,423			5,574			27,479			16,458			8,578			11,423			27,997			27,479
Depreciation		88,693			81,884			263,844			245,534			75,330			88,693			243,208			263,844
General and administrative		18,830			33,308			51,436			70,057			12,781			18,830			44,827			51,436
Impairment of assets		—			—			—			27,225			—			—			774,028			—
Restructuring and separation costs		—			649			—			4,925			344			—			17,463			—
Loss (gain) on disposition of assets		6,340			(506	)		1,191			(1,066	)
(Gain) loss on disposition of assets														(479	)		6,340			(4,132	)		1,191
Total operating expenses		326,854			309,365			937,729			925,599			227,475			326,854			1,584,767			937,729
Operating loss		(72,834	)		(23,043	)		(233,461	)		(74,906	)		(89,218	)		(72,834	)		(1,019,137	)		(233,461	)
Other income (expense):
Interest income		1,317			2,364			5,664			6,001			22			1,317			520			5,664
Interest expense, net of amounts capitalized		(31,098	)		(34,293	)		(92,182	)		(92,196	)
Foreign currency transaction (loss) gain		(77	)		(743	)		(1,883	)		115
Interest expense, net of amounts capitalized (excludes $37,834 and $62,470 of contractual interest expense on debt subject to compromise for the three- and nine-month periods ended September 30, 2020)														(98	)		(31,098	)		(42,753	)		(92,182	)
Foreign currency transaction loss														(661	)		(77	)		(1,458	)		(1,883	)
Reorganization items, net														(8,663	)		—			(62,640	)		—
Other, net		82			(179	)		520			664			107			82			349			520
Loss before income tax benefit		(102,610	)		(55,894	)		(321,342	)		(160,322	)
Income tax benefit		7,482			4,782			38,898			59,257
Loss before income tax (expense) benefit														(98,511	)		(102,610	)		(1,125,119	)		(321,342	)
Income tax (expense) benefit														(95	)		7,482			19,753			38,898
Net loss	$	(95,128	)	$	(51,112	)	$	(282,444	)	$	(101,065	)	$	(98,606	)	$	(95,128	)	$	(1,105,366	)	$	(282,444	)
Loss per share, Basic and Diluted	$	(0.69	)	$	(0.37	)	$	(2.05	)	$	(0.74	)	$	(0.71	)	$	(0.69	)	$	(8.01	)	$	(2.05	)
Weighted-average shares outstanding:
Shares of common stock		137,694			137,434			137,636			137,386			138,054			137,694			137,976			137,636
Dilutive potential shares of common stock		—			—			—			—			—			—			—			—
Total weighted-average shares outstanding		137,694			137,434			137,636			137,386			138,054			137,694			137,976			137,636

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

	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2020			2019			2020			2019
Net loss	$	(95,128	)	$	(51,112	)	$	(282,444	)	$	(101,065	)	$	(98,606	)	$	(95,128	)	$	(1,105,366	)	$	(282,444	)
Other comprehensive gains (losses), net of tax:
Derivative financial instruments:
Reclassification adjustment for gain included in net loss		(2	)		(2	)		(5	)		(5	)
Reclassification adjustment for loss (gain) included in net loss														21			(2	)		18			(5	)
Investments in marketable securities:
Unrealized holding gain		-			6			23			37			—			—			—			23
Reclassification adjustment for gain included in net loss		(8	)		(31	)		(55	)		(31	)		—			(8	)		—			(55	)
Total other comprehensive (loss) gain		(10	)		(27	)		(37	)		1
Total other comprehensive gain (loss)														21			(10	)		18			(37	)
Comprehensive loss	$	(95,138	)	$	(51,139	)	$	(282,481	)	$	(101,064	)	$	(98,585	)	$	(95,138	)	$	(1,105,348	)	$	(282,481	)

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

Three Months Ended September 30, 2019

Accumulated

Additional

Other

Total

Common Stock

Paid-In

Retained

Comprehensive

Treasury Stock

Stockholders’

Shares

Amount

Capital

Earnings

Gains (Losses)

Shares

Amount

Equity

July 1, 2019

144,764,125

$
1,448

$
2,021,095

$
1,582,099

$
(6
)

7,073,498

$
(205,739
)

$
3,398,897

Net loss

—

—

—

(95,128
)

—

—

—

(95,128
)
Stock-based compensation, net of tax

4,953

—

1,577

—

—

1,267

(12
)

1,565

Net loss on investments

—

—

—

—

(8
)

—

—

(8
)
Net loss on derivative financial
instruments

—

—

—

—

(2
)

—

—

(2
)
September 30, 2019

144,769,078

$
1,448

$
2,022,672

$
1,486,971

$
(16
)

7,074,765

$
(205,751
)

$
3,305,324

	Three Months Ended September 30, 2020
										Accumulated
					Additional					Other								Total
	Common Stock				Paid-In		Retained			Comprehensive			Treasury Stock					Stockholders’
	Shares		Amount		Capital		Earnings			Gains (losses)			Shares		Amount			Equity
July 1, 2020		145,258,536	$	1,453	$	2,029,978	$	405,441		$	(21	)		7,208,189	$	(206,162	)	$	2,230,689
Net loss		—		—		—		(98,606	)		—			—		—			(98,606	)
Stock-based compensation, net of tax		5,329		—		1		—			—			1,365		(1	)		—
Net gain on derivative financial instruments		—		—		—		—			21		��	—		—			21
September 30, 2020		145,263,865	$	1,453	$	2,029,979	$	306,835		$	-			7,209,554	$	(206,163	)	$	2,132,104

Nine Months Ended September 30, 2019

Accumulated

Additional

Other

Total

Common Stock

Paid-In

Retained

Comprehensive

Treasury Stock

Stockholders’

Shares

Amount

Capital

Earnings

Gains (Losses)

Shares

Amount

Equity

January 1, 2019

144,383,662

$
1,444

$
2,018,143

$
1,769,415

$
21

6,945,309

$
(204,370
)

$
3,584,653

Net loss

—

—

—

(282,444
)

—

—

—

(282,444
)
Stock-based compensation, net of tax

385,416

4

4,529

—

—

129,456

(1,381
)

3,152

Net loss on investments

—

—

—

—

(32
)

—

—

(32
)
Net loss on derivative financial
instruments

—

—

—

—

(5
)

—

—

(5
)
September 30, 2019

144,769,078

$
1,448

$
2,022,672

$
1,486,971

$
(16
)

7,074,765

$
(205,751
)

$
3,305,324

	Nine Months Ended September 30, 2020
										Accumulated
					Additional					Other								Total
	Common Stock				Paid-In		Retained			Comprehensive			Treasury Stock					Stockholders’
	Shares		Amount		Capital		Earnings			Gains (losses)			Shares		Amount			Equity
January 1, 2020		144,781,766	$	1,448	$	2,024,347	$	1,412,201		$	(18	)		7,077,856	$	(205,768	)	$	3,232,210
Net loss		—		—		—		(1,105,366	)		—			—		—			(1,105,366	)
Stock-based compensation, net of tax		482,099		5		5,632		—			—			131,698		(395	)		5,242
Net gain on derivative financial instruments		—		—		—		—			18			—		—			18
September 30, 2020		145,263,865	$	1,453	$	2,029,979	$	306,835		$	-			7,209,554	$	(206,163	)	$	2,132,104

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

	Three Months Ended September 30, 2019
										Accumulated
					Additional					Other								Total
	Common Stock				Paid-In		Retained			Comprehensive			Treasury Stock					Stockholders’
	Shares		Amount		Capital		Earnings			Gains (Losses)			Shares		Amount			Equity
July 1, 2019		144,764,125	$	1,448	$	2,021,095	$	1,582,099		$	(6	)		7,073,498	$	(205,739	)	$	3,398,897
Net loss		—		—		—		(95,128	)		—			—		—			(95,128	)
Stock-based compensation, net of tax		4,953		—		1,577		—			—			1,267		(12	)		1,565
Net loss on investments		—		—		—		—			(8	)		—		—			(8	)
Net loss on derivative financial instruments		—		—		—		—			(2	)		—		—			(2	)
September 30, 2019		144,769,078	$	1,448	$	2,022,672	$	1,486,971		$	(16	)		7,074,765	$	(205,751	)	$	3,305,324

	Nine Months Ended September 30, 2019
										Accumulated
					Additional					Other								Total
	Common Stock				Paid-In		Retained			Comprehensive			Treasury Stock					Stockholders’
	Shares		Amount		Capital		Earnings			Gains (Losses)			Shares		Amount			Equity
January 1, 2019		144,383,662	$	1,444	$	2,018,143	$	1,769,415		$	21			6,945,309	$	(204,370	)	$	3,584,653
Net loss		—		—		—		(282,444	)		—			—		—			(282,444	)
Stock-based compensation, net of tax		385,416		4		4,529		—			—			129,456		(1,381	)		3,152
Net loss on investments		—		—		—		—			(32	)		—		—			(32	)
Net loss on derivative financial instruments		—		—		—		—			(5	)		—		—			(5	)
September 30, 2019		144,769,078	$	1,448	$	2,022,672	$	1,486,971		$	(16	)		7,074,765	$	(205,751	)	$	3,305,324

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

Three Months Ended September 30, 2018

Accumulated

Additional

Other

Total

Common Stock

Paid-In

Retained

Comprehensive

Treasury Stock

Stockholders’

Shares

Amount

Capital

Earnings

Gains (Losses)

Shares

Amount

Equity

July 1, 2018

144,374,006

$
1,444

$
2,013,862

$
1,899,735

$
23

6,943,090

$
(204,334
)

$
3,710,730

Net loss

—

—

—

(51,112
)

—

—

—

(51,112
)
Stock-based compensation, net of tax

4,506

—

1,568

—

—

964

(20
)

1,548

Net loss on investments

—

—

—

—

(25
)

—

—

(25
)
Net loss on derivative financial instruments

—

—

—

—

(2
)

—

—

(2
)
September 30, 2018

144,378,512

$
1,444

$
2,015,430

$
1,848,623

$
(4
)

6,944,054

$
(204,354
)

$
3,661,139

Nine Months Ended September 30, 2018

Accumulated

Additional

Other

Total

Common Stock

Paid-In

Retained

Comprehensive

Treasury Stock

Stockholders’

Shares

Amount

Capital

Earnings

Gains (Losses)

Shares

Amount

Equity

December 31, 2017

144,085,292

$
1,441

$
2,011,397

$
1,964,497

$
(5
)

6,857,510

$
(203,069
)

$
3,774,261

Impact of change in accounting principle

—

—

—

(14,812
)

—

—

—

(14,812
)
Adjusted balance at January 1, 2018

144,085,292

$
1,441

$
2,011,397

$
1,949,685

$
(5
)

6,857,510

$
(203,069
)

$
3,759,449

Net loss

—

—

—

(101,065
)

—

—

—

(101,065
)
Anti-dilution payments

—

—

—

3

—

—

—

3

Stock options exercised

3,773

—

—

—

—

—

—

—

Stock-based compensation, net of tax

289,447

3

4,033

—

—

86,544

(1,285
)

2,751

Net gain on investments

—

—

—

—

6

—

—

6

Net loss on derivative financial instruments

—

—

—

—

(5
)

—

—

(5
)
September 30, 2018

144,378,512

$
1,444

$
2,015,430

$
1,848,623

$
(4
)

6,944,054

$
(204,354
)

$
3,661,139

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

	Nine Months Ended						Nine Months Ended
	September 30,						September 30,
	2019			2018			2020			2019
Operating activities:
Net loss	$	(282,444	)	$	(101,065	)	$	(1,105,366	)	$	(282,444	)
Adjustments to reconcile net loss to net cash (used in) provided by operating activities:
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation		263,844			245,534			243,208			263,844
Loss on impairment of assets		—			27,225			774,028			—
Loss (gain) on disposition of assets		1,191			(1,066	)
Reorganization items, net								22,107			—
(Gain) loss on disposition of assets								(4,132	)		1,191
Deferred tax provision		(48,323	)		(69,109	)		(16,865	)		(48,323	)
Stock-based compensation expense		4,533			4,036			5,637			4,533
Contract liabilities, net		15,060			(6,589	)		9,814			15,060
Contract assets, net		302			(4,395	)		3,048			302
Deferred contract costs, net		49,866			34,901			(2,578	)		49,866
Long-term employee remuneration programs								(4,803	)		1,609
Noncurrent collateral deposits								(18,262	)		—
Other assets, noncurrent		180			823			(8,513	)		180
Other liabilities, noncurrent		(90	)		(4,298	)		(3,240	)		(90	)
Other		2,408			3,969			2,964			799
Changes in operating assets and liabilities:
Accounts receivable		(27,177	)		57,881			107,148			(27,177	)
Prepaid expenses and other current assets		(128	)		4,901			3,957			(128	)
Accounts payable and accrued liabilities		7,115			(11,836	)		(10,440	)		7,115
Taxes payable		(548	)		7,844			9,728			(548	)
Net cash (used in) provided by operating activities		(14,211	)		188,756
Net cash provided by (used in) operating activities								7,440			(14,211	)
Investing activities:
Capital expenditures		(249,819	)		(159,751	)		(162,621	)		(249,819	)
Proceeds from sale of foreign bonds								5,915			—
Proceeds from maturities of marketable securities		2,300,000			775,000			—			2,300,000
Purchase of marketable securities		(1,996,996	)		(1,047,453	)		—			(1,996,996	)
Proceeds from disposition of assets, net of disposal costs		16,097			69,533			5,378			16,097
Net cash provided by (used in) investing activities		69,282			(362,671	)
Net cash (used in) provided by investing activities								(151,328	)		69,282
Financing activities:
Borrowings under credit facility								436,000			—
Other		(12	)		(269	)		—			(12	)
Net cash used in financing activities		(12	)		(269	)
Net change in cash and cash equivalents		55,059			(174,184	)
Cash and cash equivalents, beginning of period		154,073			376,037
Cash and cash equivalents, end of period	$	209,132		$	201,853
Net cash provided by (used in) financing activities								436,000			(12	)
Net change in cash, cash equivalents and restricted cash								292,112			55,059
Cash, cash equivalents and restricted cash, beginning of period								156,281			154,073
Cash, cash equivalents and restricted cash, end of period							$	448,393		$	209,132

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

The unaudited condensed consolidated financial statements of Diamond Offshore Drilling, Inc. and subsidiaries, which we refer to as “Diamond Offshore,” “we,” “us” or “our,” should be read in conjunction with our Annual Report on Form ~~10-K~~10-K/A for the year ended December 31, ~~2018~~2019 (File No. 1-13926).

As of October ~~25, 2019,~~29, 2020, Loews Corporation owned approximately 53% of the outstanding shares of our common stock.

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the ~~U.S.,~~United States, or 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 comprehensive ~~income or~~ loss, 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.

The preparation of financial statements in conformity with 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.

In ~~February~~June 2016, the Financial Accounting Standards Board, or FASB, issued Accounting Standards Update, or ~~ASU, No. 2016-02,~~ ~~Leases~~ (Topic 842), or ASU 2016-02, which (i) requires lessees to recognize a right of use asset and a lease liability on the balance sheet for most leases, (ii) updates previous accounting standards for lessors to align certain requirements with the updates to lessee accounting standards and the revenue recognition accounting standards and (iii) requires enhanced disclosure of qualitative and quantitative information about an entity's leasing arrangements.

We adopted ASU 2016-02 effective January 1, 2019 using an optional transition method requiring leases existing at, or entered into after, January 1, 2019 to be recognized and measured under the new accounting standard. Prior period amounts have not been adjusted and continue to be reflected in accordance with our historical accounting for leases. In our adoption of ASU 2016-02, we also utilized a transition practical expedient package whereby we did not reassess (i) whether any of our expired or existing contracts contain a lease, (ii) the classification for any expired or existing leases and (iii) initial direct costs for any existing leases. The adoption of this standard resulted in the recording of operating lease assets and offsetting operating lease liabilities of $146.8 million as of January 1, 2019, with no related impact on our unaudited Condensed Consolidated Statements of Stockholders’ Equity. See Note 9.

Upon adoption of ASU 2016-02, we concluded that our drilling contracts contain a lease component for the use of our drilling rigs based on the updated definition of a lease. However, ASU 2016-02 provides for a practical expedient for lessors whereby, under certain circumstances, the lessor may combine the lease and non-lease components and account for the combined component in accordance with the accounting treatment for the predominant component. We have determined that our current drilling contracts qualify for this practical expedient and have combined the lease and service components of our standard drilling contracts. We continue to account for the combined component under ASU No. 2014-09, ~~Revenue from Contracts with Customers (Topic 606) and its related amendments, or collectively Topic 606~~.

~~In June 2016, the FASB issued~~ ASU, No. 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, or ASU 2016-13. ASU 2016-13 ~~requires changes~~replaces the incurred loss impairment methodology under previous GAAP by requiring entities to ~~the recognition of~~measure credit losses onof certain financial ~~instruments not accounted for at fair value through net income,~~assets, including ~~loans, debt securities,~~ trade receivables, ~~net investments in leases and available-for-sale debt securities. The amended standard broadens the information~~utilizing a methodology that ~~an entity must consider in developing its estimate of~~reflects expected credit losses ~~requiring an entity to estimate credit losses over the life~~and requires consideration of ~~an exposure based on historical information, current information and~~a broader range of reasonable and supportable ~~forecasts. The guidance is~~information to inform credit loss estimates.

We adopted ASU 2016-13 and its related amendments, or collectively, CECL, effective ~~for interim and annual periods beginning after December 15, 2019 and will be applied using~~January 1, 2020, by recognizing a ~~modified retrospective method with a cumulative effect~~cumulative-effect adjustment which was not material to ~~beginning retained earnings. We are currently evaluating the effect the guidance will have on~~ our unaudited condensed consolidated financial statements. CECL has been applied prospectively and therefore prior periods have not been adjusted. See Notes 5 and 7.

We maintain restricted cash bank accounts, which are subject to restrictions pursuant to a Bankruptcy Court order, to settle certain professional fees incurred upon or prior to our emergence from bankruptcy. See Note 2.

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 September 30, 2020, our restricted cash was considered to be current and was recorded in “Restricted cash” in our unaudited Condensed Consolidated Balance Sheets. See Note 7.

~~The $1.0~~We reported the aggregate $2.0 million net book value of the Ocean ~~Confidence~~America and Ocean Rover, aboth previously impaired semisubmersible ~~rig~~rigs that ~~was~~were cold stacked in 2015 ~~has been reported~~and 2016, respectively, as ~~“Asset~~“Assets held for sale” in our unaudited Condensed Consolidated Balance Sheets at September 30, ~~2019.~~2020.

On April 26, 2020 (or the Petition Date), Diamond Offshore Drilling, Inc. (or the Company) and certain of its direct and indirect subsidiaries (which we refer to, together with the Company, as the Debtors) filed voluntary petitions for relief under chapter 11 (or Chapter 11) of title 11 of the United States Code (or the Chapter 11 Cases) in the United States Bankruptcy Court for the Southern District of Texas (or the Bankruptcy Court). The Chapter 11 Cases are jointly administered under the caption In re Diamond Offshore Drilling, Inc., et al., Case No. 20-32307.

The Debtors filed motions with the Bankruptcy Court seeking authorization to continue to operate their businesses as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the United States Bankruptcy Code (or the Bankruptcy Code) and orders of the Bankruptcy Court. To ensure their ability to continue operating in the ordinary course of business, the Debtors filed with the Bankruptcy Court a variety of motions seeking “first day” relief, including authority to continue using their cash management system, pay employee wages and benefits and pay certain vendors and suppliers in the ordinary course of business (or the First Day Motions), all of which were approved.

Pursuant to the First Day Motions, and subject to certain terms and dollar limits included therein, the Debtors were authorized to continue to use their unrestricted cash on hand, as well as all cash generated from daily operations, which is being used to continue the Debtors’ operations without interruption during the course of their restructuring. Also pursuant to the First Day Motions, the Debtors received Bankruptcy Court authorization to, among other things and subject to the terms and conditions set forth in the applicable orders, pay prepetition employee wages, salaries, health benefits and other employee obligations during their restructuring, pay certain claims relating to critical and other vendors, continue their cash management programs and insurance policies and continue to honor their current customer programs. The Debtors are authorized under the Bankruptcy Code to pay post-petition expenses incurred in the ordinary course of business without seeking Bankruptcy Court approval. Until a plan of reorganization is approved and effective, the Debtors will continue to manage their properties and operate their businesses as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code and the orders of the Bankruptcy Court.

Commencement of the Chapter 11 Cases automatically stayed most actions against the Debtors, including actions to collect indebtedness incurred prior to the Petition Date, actions to enforce pre-Petition Date contractual rights or remedies against the Debtors and actions to exercise control over the Debtors’ property. Subject to certain exceptions under the Bankruptcy Code, the commencement of the Chapter 11 Cases also automatically stayed the continuation of most legal proceedings or the filing of other actions against the Debtors or their property to recover on, collect, or secure a claim arising prior to the Petition Date or to exercise control over property of the Debtors’ bankruptcy estates, unless and until the Bankruptcy Court modifies or lifts the automatic stay as to any such claim. Notwithstanding the general application of the automatic stay described above, governmental authorities may determine to continue actions brought under their police and regulatory powers.

The U.S. Trustee for the Southern District of Texas filed a notice appointing an official committee of unsecured creditors on May 11, 2020, which was subsequently reconstituted on June 11, 2020 and September 14, 2020.

On May 27, 2020, the Bankruptcy Court approved a new key employee retention plan and a new non-executive incentive plan covering certain non-executive key employees. On June 23, 2020, the Bankruptcy Court approved a key employee incentive plan covering certain additional key employees, including our executive officers. Upon the participating employee’s acceptance of an award under the new compensation plans, all outstanding unvested incentive awards previously granted to the employee under our previously-existing incentive plans, consisting of restricted stock units (or RSUs), stock appreciation rights (or SARs) and/or cash incentive awards, were canceled.

As of September 30, 2020, the Debtors had not emerged from bankruptcy and no plan of reorganization or restructuring support agreement had been filed with the Bankruptcy Court. Negotiations between the various parties to the Chapter 11 Cases are ongoing. A plan of reorganization, if and when approved by the Bankruptcy Court, could materially change the amounts and classifications of assets and liabilities reported in the accompanying unaudited condensed consolidated financial statements.

During the first quarter of 2020, the business climate in which we operate experienced a significant adverse change, primarily as a result of the market impacts of the oil price war between Saudi Arabia and Russia and regulatory, market and commercial challenges that arose due to the COVID-19 pandemic and efforts to mitigate the spread of the virus, both of which resulted in a dramatic decline in oil prices. As a result of the filing of the Chapter 11 Cases, the principal and interest due under our outstanding senior notes and revolving credit facility became immediately due and payable and have been presented as “Liabilities subject to compromise” in our unaudited Condensed Consolidated Balance Sheets at September 30, 2020. However, any efforts to enforce such payment obligations with respect to our senior notes and revolving credit facility are automatically stayed as a result of the filing of the Chapter 11 Cases. We have projected that we will not have sufficient cash on hand or available liquidity to repay all such outstanding debt. For the nine months ended September 30, 2020, we reported a net loss of $1.1 billion, inclusive of a pre-tax $774.0 million impairment charge.

These conditions and events raise substantial doubt over our ability to continue as a going concern for twelve months after the date our financial statements are issued. Financial information in this report has been prepared on the basis that we will continue as a going concern, which presumes that we will be able to realize our assets and discharge our liabilities in the normal course of business as they come due. Financial information in this report does not reflect the adjustments to the carrying values of assets and liabilities and the reported expenses and balance sheet classifications that would be necessary if we were unable to realize our assets and settle our liabilities as a going concern in the normal course of operations. Such adjustments could be material.

Our long-term liquidity requirements and the adequacy of capital resources are difficult to predict at this time. Although we anticipate that the Chapter 11 Cases will help address our liquidity concerns, as of September 30, 2020, we do not have a plan of reorganization in place. Additionally, the approval of a plan of reorganization is not within our control and uncertainty remains over the Bankruptcy Court's approval of a plan of reorganization. As such, due to the absence of a plan of reorganization and lack of clarity regarding emergence from bankruptcy, we have concluded that substantial doubt continues to exist about our ability to continue as a going concern.

We have prepared our unaudited condensed consolidated financial statements as if we were a going concern and in accordance with FASB Accounting Standards Codification Topic No. 852 – Reorganizations, or ASC 852.

Prepetition Restructuring Charges. We have reported legal and other professional advisor fees incurred in relation to the Chapter 11 Cases, but prior to the Petition Date, as “Restructuring and separation costs” in our unaudited Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2020. See Note 11 for a discussion of other costs included in “Restructuring and separation costs.”

Reorganization Items. Expenditures, gains and losses that are realized or incurred by the Debtors subsequent to the Petition Date and as a direct result of the Chapter 11 Cases are reported as “Reorganization items, net” in our unaudited Condensed Consolidated Statements of Operations. These costs include legal and other professional advisory service fees pertaining to the Chapter 11 Cases and all adjustments made to the carrying amount of certain prepetition liabilities reflecting claims expected to be allowed by the Bankruptcy Court.

The following table provides information about reorganization items incurred during the three- and nine-month periods ended September 30, 2020, subsequent to the Petition Date (in thousands):

Payments of $23.8 million related to professional fees and vendor cancellation costs have been presented as cash outflows from operating activities in our unaudited Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2020. See Note 5.

Liabilities Subject to Compromise. We have reported prepetition unsecured and under-secured obligations that may be impacted by the Chapter 11 Cases as “Liabilities subject to compromise” in our unaudited Condensed Consolidated Balance Sheets at September 30, 2020. ASC 852 requires prepetition liabilities that are subject to compromise to be reported at the amounts expected to be allowed by the Bankruptcy Court. The amounts currently reported as liabilities subject to compromise are preliminary and may be subject to future adjustment depending on Bankruptcy Court actions, further developments with respect to disputed claims, determinations of the secured status of certain claims, the values of any collateral securing such claims, rejection of executory contracts, continued reconciliation or other events. These amounts represent our best estimate of allowed claims that will be resolved as part of the bankruptcy proceedings but may be ultimately settled for a lesser amount. We will continue to evaluate these liabilities throughout the Chapter 11 Cases and adjust amounts as necessary. Such adjustments may be material.

Liabilities subject to compromise at September 30, 2020 consist of the following (in thousands):

Upon filing of the Chapter 11 Cases on April 26, 2020, we ceased accruing interest on our senior unsecured debt and borrowings under our credit facility. As a result, we did not record $28.3 million and $48.5 million of contractual interest expense related to our senior notes for the three and nine months ended September 30, 2020, respectively, and $9.5 million and $13.9 million of contractual interest expense related to borrowings under our credit facility for the three- and nine-month periods ended September 30, 2020, respectively.

Unaudited condensed combined financial statements of the Debtors are set forth below. These financial statements exclude the financial statements of the non-Debtor subsidiaries. Transactions and balances of receivables and payables between the Debtors have been eliminated in consolidation. Amounts payable to the non-Debtor subsidiaries are reported in the unaudited condensed consolidated balance sheet of the Debtors.

DIAMOND OFFSHORE DRILLING, INC. AND CERTAIN SUBSIDIARIES PARTY TO THE BANKRUPTCY CASES (DEBTOR-IN-POSSESSION)

	Nine Months Ended
	September 30,
	2020
Operating activities:
Net loss	$	(1,107,433	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation		242,480
Loss on impairment of assets		774,028
Reorganization items, net		22,107
Gain on disposition of assets		(3,989	)
Deferred tax provision		(16,846	)
Stock-based compensation expense		5,637
Contract liabilities, net		13,595
Contract assets, net		2,762
Deferred contract costs, net		(8,085	)
Long-term employee remuneration programs		(5,079	)
Noncurrent collateral deposits		(18,262	)
Other assets, noncurrent		(8,756	)
Other		3,013
Changes in operating assets and liabilities:
Accounts receivable		68,908
Prepaid expenses and other current assets		15,022
Accounts payable and accrued liabilities		1,439
Taxes payable		(15,462	)
Due to non-debtor subsidiaries		47,111
Net cash provided by operating activities		12,190
Investing activities:
Capital expenditures		(156,885	)
Capital contribution to non-debtor subsidiary		(5,724	)
Proceeds from disposition of assets, net of disposal costs		5,235
Net cash used in investing activities		(157,374	)
Financing activities:
Borrowings under credit facility		436,000
Net cash provided by financing activities		436,000
Net change in cash, cash equivalents and restricted cash		290,816
Cash, cash equivalents and restricted cash, beginning of period		142,098
Cash, cash equivalents and restricted cash, end of period	$	432,914

The activities that primarily drive the revenue earned from our contract drilling ~~contracts~~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.

~~Dayrate and other revenue for activities that correspond to a distinct time increment within the contract term are recognized in the period in which the services are performed.~~ 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 isare allocated across the single performance obligation and recognized ratably ~~in proportion to the actual services performed~~ 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.

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

	September 30,			December 31,			September 30,			December 31,
	2019			2018			2020			2019
Trade receivables	$	185,934		$	160,463		$	123,025		$	199,572
Current contract assets ⁽¹⁾		8,638			6,832			3,266			6,314
Noncurrent contract assets ⁽¹⁾		—			2,107
Current contract liabilities (deferred revenue) ⁽¹⁾		(6,056	)		(2,803	)		(45,389	)		(9,573	)
Noncurrent contract liabilities (deferred revenue) ⁽¹⁾		(29,531	)		(17,723	)		(12,529	)		(38,531	)

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

The following table reflects the specified types of revenue expected to be recognized in the future related to unsatisfied performance obligations as of September 30, ~~2019~~2020 (in thousands):

	For the Years Ending December 31,										For the Years Ending December 31,
	2019 ⁽¹⁾		2020		2021		2022		Total		2020 ⁽¹⁾		2021		2022		Total
Mobilization and contract preparation revenue	$	714	$	2,270	$	632	$	124	$	3,740	$	3,024	$	26,156	$	2,600	$	31,780
Capital modification revenue		1,612		4,934		228		—		6,774		4,393		13,963		1,466		19,822
Blended rate revenue		—		21,410		7,007		—		28,417
Blended rate revenue and other												3,138		14,092		169		17,399
Total	$	2,326	$	28,614	$	7,867	$	124	$	38,931	$	10,555	$	54,211	$	4,235	$	69,001

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. Revenue expected to be recognized in the future related to the blending of rates when a contract has operating dayrates that decrease over the initial contract term is also included. 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 September 30, ~~2019.~~2020. 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 ASU No. 2014-09, Revenue from Contracts with Customers (Topic ~~606~~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.

~~2019~~2020 Evaluation. ~~During~~For the third quarter ~~of 2019,~~ended September 30, 2020, we evaluated 3 of our drilling rigs ~~that had~~with indicators of impairment. Based on our assumptions and analysis at that time, we determined that the undiscounted probability-weighted cash flow for each rig was in excess of its respective carrying value. As a result, we concluded that 0 impairment of these rigs had occurred at September 30, ~~2019.~~2020.

As discussed in Note 2, during the first quarter of 2020, the business climate in which we operate experienced a significant adverse change, which resulted in a dramatic decline in oil prices. During the first quarter of 2020, we evaluated 5 of our drilling rigs that had indicators of impairment. Based on our assumptions and analysis at that time, we determined that the carrying value of 4 of these rigs was impaired (we collectively refer to these four rigs as the 2020 Impaired Rigs).

We estimated the fair values of the 2020 Impaired Rigs using an income approach, whereby the fair value of each 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 each rig. Our fair value estimates were representative of Level 3 fair value measurements due to the significant level of estimation involved and the lack of transparency as to the inputs used.

We recorded aggregate impairments of $774.0 million for the nine months ended September 30, ~~2019, there were 10 rigs~~2020 related to our 2020 Impaired Rigs. See Note 7.

We evaluate our property and equipment for impairment whenever changes in ~~our drilling fleet not previously written down to scrap, for which there were no current indicators~~circumstances indicate that ~~their~~the carrying ~~amounts~~amount of an asset may not be ~~recoverable and, thus, were not evaluated for impairment.~~recoverable. If market fundamentals in the offshore oil and gas industry deteriorate further or a ~~projected~~ market recovery is further delayed, we may be required to recognize additional impairment ~~losses~~charges in future periods.

~~2018 Impairment.~~ ~~During the second quarter of 2018, we recorded an impairment loss of $27.2 million to recognize a reduction in fair value of the~~ ~~Ocean Scepter~~, a jack-up rig that was marketed for sale at that time. We estimated the fair value of the impaired jack-up rig using a market approach based on a signed agreement to sell the rig, less estimated costs to sell. We considered this valuation approach to be a Level 3 fair value measurement due to the level of estimation involved as the sale had not yet been completed at the time of our analysis. The ~~Ocean Scepter~~ ~~was sold in July 2018.~~

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

	September 30,			December 31,			September 30,			December 31,
	2019			2018			2020			2019
Trade receivables	$	185,934		$	160,463		$	123,025		$	199,572
Value added tax receivables								12,505			17,716
Federal income tax receivables		38,574			—			8,420			38,574
Value added tax receivables		18,266			13,237
Related party receivables		132			174			75			166
Other		174			205			232			287
		243,080			174,079			144,257			256,315
Allowance for bad debts		(5,459	)		(5,459	)
Allowance for credit losses								(5,633	)		(5,459	)
Total	$	237,621		$	168,620		$	138,624		$	250,856

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

	September 30,		December 31,		September 30,		December 31,
	2019		2018		2020		2019
Deferred contract costs	$	26,252	$	70,021	$	18,770	$	20,019
Prepaid taxes						15,174		12,475
Rig spare parts and supplies		17,331		20,256		13,465		18,250
Current contract assets		8,638		6,832		3,266		6,314
Prepaid insurance						3,247		2,892
Prepaid rig costs		4,041		5,247		2,459		2,990
Prepaid insurance		3,587		2,742
Prepaid taxes		826		54,412
Prepaid legal retainers						2,454		—
Other		5,994		3,886		4,434		5,718
Total	$	66,669	$	163,396	$	63,269	$	68,658

	September 30,		December 31,		September 30,		December 31,
	2019		2018		2020		2019
Deferred revenue					$	45,389	$	9,573
Payroll and benefits						31,652		42,494
Shorebase and administrative costs						19,890		5,275
Rig operating expenses						17,355		37,969
Personal injury and other claims						6,210		7,074
Accrued capital project/upgrade costs	$	39,169	$	37,379		4,772		56,603
Payroll and benefits		38,370		47,564
Current operating lease liability						620		20,030
Interest payable		36,813		28,234		—		28,234
Rig operating expenses		35,422		42,323
Current operating lease liability		19,143		-
Personal injury and other claims		6,790		5,544
Deferred revenue		6,056		2,803
Shorebase and administrative costs		4,871		6,217
Other		3,570		2,164		1,628		3,528
Total	$	190,204	$	172,228	$	127,516	$	210,780

~~We adopted ASU 2016-02 effective January 1, 2019, which required us to recognize a right of use asset and a lease liability on the balance sheet for most leases. See Note 9.~~

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

	Nine Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2020			2019
Accrued but unpaid capital expenditures at period end	$	39,169		$	19,413		$	5,242		$	39,169
Common stock withheld for payroll tax obligations ⁽¹⁾		1,381			1,285			395			1,381
Cash interest payments		76,219			76,219			19,843			76,219
Cash paid for reorganization items, net								23,818			—
Cash income taxes paid, net of (refunds):
Foreign		13,227			5,941			11,229			13,227
U.S. Federal		—			(7,389	)		(42,462	)		—
State		(15	)		2			36			(15	)

In June 2020, we received Trinidad bonds in settlement of a VAT receivable. The bonds were valued at $5.7 million based on third-party quotes received, which approximated the amount of the settled receivable. During the third quarter of 2020, we sold the bonds for proceeds of $5.9 million.

We present basic and diluted net ~~income (loss)~~loss per share on our unaudited Condensed Consolidated Statements of Operations. Basic net ~~income (loss)~~loss per share excludes dilution and is computed by dividing net ~~income (loss)~~loss by the weighted-average number of shares of common ~~shares~~stock outstanding for the period. Diluted net income (loss) per share reflects the potential dilution that could occur if securities or other contracts to issue common stock (common share equivalents) were exercised or converted into common stock, unless the effect would be antidilutive. For all periods in which we experience a net loss, all shares of common stock issuable upon exercise of outstanding stock appreciation rights and vesting of outstanding restricted stock units have been excluded from the calculation of weighted-average shares because their inclusion would be antidilutive.

The following table sets forth the ~~share effects of~~ stock-based awards excluded from the computations of diluted loss per share (in thousands).:

	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2020		2019		2020		2019
Employee and director:
Stock appreciation rights		970		1,071		995		1,161		607		970		636		995
Restricted stock units		1,261		1,182		1,188		1,150		—		1,261		—		1,188

Financial instruments that potentially subject us to significant concentrations of credit or market risk consist primarily of periodic temporary investments of excess cash, trade accounts receivable and investments in debt securities. We generally place our excess cash investments in U.S. Treasury bills and U.S. government-backed short-term money market instruments through several financial institutions. We periodically evaluate the relative credit standing of these financial institutions as part of our investment strategy.

Our credit risk ~~with respect~~corresponds primarily to ~~our~~ trade ~~accounts receivable are limited primarily due to~~receivables. Since the ~~entities comprising our customer base. The~~ market for our services is the offshore oil and gas industry, ~~and~~ our customer base ~~has consisted~~consists primarily of major and independent oil and gas companies, ~~and~~as well as government-owned oil companies. ~~Based on our current customer base and the geographic areas in which~~At September 30, 2020, we ~~operate, we do not~~ believe that we have ~~any~~potentially significant concentrations of credit risk ~~at September 30, 2019.~~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, ~~to us,~~ we perform a credit review on that ~~customer.~~customer, including a review of its credit ratings and financial statements. Based on that ~~analysis,~~credit review, we may require that the customer ~~present~~have a bank issue a letter of credit on its behalf, prepay for the services in advance or provide other credit enhancements. We ~~record~~currently have one customer for which we have required a ~~provision~~letter of credit to guarantee $12.8 million of the revenue to be earned pursuant to a contract extension amendment signed during the third quarter of 2020. We have not required any other credit enhancements by our customers or required any to pay for ~~bad debts~~services in advance at September 30, 2020. 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 September 30, 2020, $6.4 million in trade receivables were considered past due by 30 days or more, of which $5.5 million were fully reserved for in previous years and the remaining $0.9 million were less than 90 days past due and considered collectible.

Pursuant to ASU 2016-13, 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 ~~case-by-case basis when facts~~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 ~~circumstances indicate that a customer receivable may not be collectible~~future anticipated economic conditions in determining our credit loss factor, including crude oil prices and ~~historically, losses on~~liquidity of credit markets. In applying the requirements of CECL, we segregated our trade receivables ~~have been infrequent occurrences.~~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 January 1, 2020 and September 30, 2020, 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 $0.2 million at September 30, 2020, which included the cumulative adjustment recorded for the initial adoption of ASU 2016-13. Due to immateriality, the cumulative adjustment was recorded in “Contract drilling, excluding depreciation” expense in our unaudited Condensed Consolidated Statements of Operations instead of in opening retained earnings as prescribed in ASU 2016-13. Our total allowance for credit losses was $5.6 million and $5.5 million at September 30, 2020 and December 31, 2019, respectively. See Notes 1 and 5.

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:

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. We recorded an impairment charge related to four of our drilling rigs, which were measured at fair value on a nonrecurring basis at March 31, 2020, and have presented the aggregate loss in “Impairment of assets” in our unaudited Condensed

Consolidated Statements of Operations for the nine months ended September 30, 2020. We had 0 assets measured at fair value on a recurring basis at September 30, 2020.

~~We had no Level 2 or Level 3 assets or liabilities as of September 30, 2019 or December 31, 2018.~~

We believe that the carrying amounts of our other financial assets and liabilities (excluding ~~long-term debt)~~our senior notes), which are not measured at fair value in our unaudited Condensed Consolidated Balance Sheets, approximate fair value based on the following assumptions:

Our senior notes are not measured at fair value; however, under the GAAP fair value hierarchy, our ~~long-term debt~~senior notes would be considered Level 2 liabilities. The fair value of our senior notes was derived using a third-party pricing service at September 30, ~~2019~~2020 and December 31, ~~2018.~~2019. We perform control procedures over information we obtain from pricing services and brokers to test whether prices received represent a reasonable estimate of fair value. These procedures include the review of pricing service or broker pricing methodologies and comparing fair value estimates to actual trade activity executed in the market for these instruments occurring generally within a 10-day period of the report date.

Fair values and related carrying values of our senior notes are shown below (in millions).

	September 30, 2019				December 31, 2018				September 30, 2020				December 31, 2019
	Fair Value		Carrying Value		Fair Value		Carrying Value		Fair Value		Carrying Value		Fair Value		Carrying Value
3.45% Senior Notes due 2023	$	187.5	$	249.5	$	185.0	$	249.5	$	23.8	$	250.0	$	212.5	$	249.6
7.875% Senior Notes due 2025		392.5		497.2		415.0		496.8		46.4		500.0		435.0		497.1
5.70% Senior Notes due 2039		242.5		497.3		305.0		497.2		44.4		500.0		292.5		497.3
4.875% Senior Notes due 2043		346.9		748.9		416.3		748.9		69.0		750.0		408.8		749.0

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.

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

	September 30,			December 31,			September 30,			December 31,
	2019			2018			2020			2019
Drilling rigs and equipment	$	7,911,380		$	8,210,824		$	7,026,827		$	8,004,489
Land and buildings		64,102			63,757			64,076			64,267
Office equipment and other		91,952			91,819			92,216			92,289
Cost		8,067,434			8,366,400			7,183,119			8,161,045
Less: accumulated depreciation		(2,916,558	)		(3,182,178	)		(2,940,013	)		(3,008,217	)
Drilling and other property and equipment, net	$	5,150,876		$	5,184,222		$	4,243,106		$	5,152,828

~~In April 2019,~~During the first quarter of 2020, we ~~sold the~~ ~~Ocean Guardian~~, a previously impaired semisubmersible rig, for a net pre-tax gain of $14.3 million. In addition, during the nine months ended September 30, 2019, we disposed of certain other property and equipment and recognizedrecorded an aggregate ~~net pre-tax loss~~impairment charge of ~~$15.5 million. During~~$774.0 million, to write down 4 of our drilling rigs with indicators of impairment to their estimated fair values. See Notes 4 and 7. In the ~~third~~second quarter of ~~2019,~~ 2020, we transferred the net book value of the Ocean ~~Confidence~~America and Ocean Rover, atwo previously impaired semisubmersible ~~rig,~~rigs, to ~~“Asset~~“Assets held for sale” in our unaudited Condensed Consolidated Balance Sheets at September 30, ~~2019.~~2020.

8.Effective March 17, 2020, we terminated our $225.0 million revolving credit agreement, which was scheduled to mature on October 22, 2020. At the time of termination, there were no borrowings outstanding under the facility. We did not incur any early termination penalties in connection with the termination and wrote off $0.5 million in deferred arrangement fees associated with the facility.

In March 2020, we borrowed $436.0 million under our $950.0 million senior 5-year revolving credit agreement, or Credit Agreement, which we entered into on October 2, 2018. The weighted average interest rate on the combined borrowings at September 30, 2020 was 6.64%. The principal and interest under the Credit Agreement became immediately due and payable upon filing of the Chapter 11 Cases, which constituted an event of default under the Credit Agreement. Also, as a result of the filing of the Chapter 11 Cases, we received notification on April 28, 2020 that the commitments under our Credit Agreement had been reduced from $950 million to approximately $442.0 million, representing the amount of borrowings outstanding plus the value of a $6.0 million financial letter of credit, which was issued in January 2020 under the Credit Agreement in support of a previously issued surety bond. The outstanding borrowings and accrued interest have been presented as “Liabilities subject to compromise” in our unaudited Condensed Consolidated Balance Sheets at September 30, 2020.

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 ~~reasonably estimated,~~determined, we record a liability for the amount of the ~~reasonably~~ 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.

We are one of several unrelated defendants in lawsuits filed in Louisiana state courts alleging that defendants manufactured, distributed or utilized drilling mud containing asbestos and, in our case, allowed such drilling mud to have been utilized aboard our drilling rigs. The plaintiffs seek, among other things, an award of unspecified

compensatory and punitive damages. The manufacture and use of asbestos-containing drilling mud had already ceased before we acquired any of the drilling rigs addressed in these lawsuits. We believe that we are not liable for the damages asserted in the lawsuits pursuant to the terms of our 1989 asset purchase agreement with Diamond M Corporation. We are unable to estimate our potential exposure, if any, to these lawsuits at this time but do not believe that our ultimate liability, if any, resulting from this litigation will have a material effect on our consolidated financial condition, results of operations or cash flows.

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 these taxes and the related penalties and interest and, accordingly, have recorded a $12.4 million and $16.1 million liability at September 30, 2020 and December 31, 2019, respectively. 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 consolidated financial condition, results of operations or cash flows.

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. Additionally, tax authorities in Brazil have issued tax assessments on intercompany revenue between our subsidiaries doing business in Brazil that, if upheld by the Brazilian courts, could result in additional taxes, interest and penalties for which the fully assessed amounts would be material to our financial statements. 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,~~condition, results of operations or cash flows.

Under our insurance policies, our deductibles for marine liability insurance coverage 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, are $5.0 million for the first occurrence and vary in amounts ranging between $5.0 million and, if aggregate claims exceed certain thresholds, 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. Our deductibles for personal injury claims arising due to named windstorms in the U.S. Gulf of Mexico are $25.0 million for the first occurrence and vary in amounts ranging between $25.0 million and, if aggregate claims exceed certain thresholds, 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 September 30, ~~2019~~2020 our estimated liability for personal injury claims was ~~$21.1~~$14.8 million, of which $6.2 million and ~~$14.9~~$8.6 million were recorded in “Accrued liabilities” and “Other liabilities,” respectively, in our unaudited Condensed Consolidated Balance Sheets. At December 31, ~~2018~~2019 our estimated liability for personal injury claims was ~~$27.9~~$17.4 million, of which ~~$5.2~~$6.4 million and ~~$22.7~~$11.0 million were recorded in “Accrued liabilities” and “Other liabilities,” respectively, in our Consolidated Balance Sheets. The eventual settlement or adjudication of these claims could differ materially from our estimated amounts due to uncertainties such as:

We were contingently liable as of September 30, ~~2019~~2020 in the aggregate amount of ~~$34.8~~$31.2 million under certain customs, performance, tax and VAT bonds and letters of credit. Agreements relating to approximately ~~$26.2~~$22.9 million of these tax and customs bonds can require collateral at any ~~time. As of September 30, 2019, we had not been required to make any collateral deposits with respect to these agreements. The~~time, while the remaining agreements, aggregating ~~$8.6~~$8.3 million, cannot require collateral except in events of default.

~~Our leasing activities primarily consist~~ During the first quarter of operating leases for shorebase offices, office and information technology equipment, employee housing, vehicles, onshore storage yards and certain rig equipment and tools. Our leases have terms ranging from one month to ten years, some2020, we issued a $6.0 million financial letter of ~~which include options to extend the lease for up to five years and/or to terminate the lease within one year.~~

~~Additionally,~~credit as collateral in support of our outstanding surety bonds. Also, in April 2020, we ~~are participants in four sale and leaseback arrangements with a subsidiary~~made cash collateral deposits of General Electric Company, or GE, pursuant to the 2016 sale of certain blowout preventers and related well control equipment, or Well Control Equipment, on our drillships and corresponding agreements to lease back that equipment under ten-year operating leases for approximately $26$17.5 million per year in the aggregate with renewal options for two successive five-year periods. At the time of the transactions with GE, the carrying value of the Well Control Equipment exceeded the aggregate proceeds received from the sale, resulting in the recognition of prepaid rent, which was being amortized over the respective terms of the leases. On January 1, 2019, as a result of the adoption of ASU 2016-02, the aggregate remaining prepaid rent balances of $3.9 million and $10.6 million, previously recorded as “Prepaid expenses and other current assets” and “Other assets,” respectively, were reclassified to a right-of-use lease asset within “Other assets” in our unaudited Condensed Consolidated Balance Sheets and continue to be amortized over the remaining terms of the leases. In connection with the sale and leaseback transactions, we also entered into a ten-year service agreement with a subsidiary of Baker Hughes Company (formerly named Baker Hughes, a GE Company) pertaining to the Well Control Equipment. Such services include management of maintenance, certification and reliability with respect to ~~such equipment.~~

~~In applying 2016-02, we utilize an exemption for short-term leases whereby we do not record leases with terms~~other bonds and letters of one year or less on the balance sheet. We have also made an accounting policy election not to separate lease components from non-lease components for each of our classes of underlying assets, except for subsea equipment,credit, which includes the Well Control Equipment discussed above. At inception, the consideration for the overall Well Control Equipment arrangement was allocated between the lease and service components based on an estimation of stand-alone selling price of each component, which maximized observable inputs. The costs associated with the service portion of the agreement are accounted for separately from the cost attributable to the equipment leases based on that allocation and thus, are not included in our right-of-use lease asset or lease liability balances. The non-lease components for each of our other classes of assets generally relate to maintenance, monitoring and security services and are not separated from their respective lease components.

The lease term used for calculating our right-of-use assets and lease liabilities is determined by considering the noncancelable lease term, as well as any extension options that we are reasonably certain to exercise. The determination to include option periods is generally made by considering the activity in the region or for the rig corresponding to the respective lease, among other contract-based and market-based factors. We have used our incremental borrowing rate to discount future lease payments as the rate implicit in our leases is not readily determinable. To arrive at our incremental borrowing rate, we consider our unsecured borrowings and then adjust those rates to assume full collateralization and to factor in the individual lease term and payment structure.

Total operating lease expense for the three and nine months ended September 30, 2019 was $9.7 million and $28.6 million, respectively, of which $0.8 million and $2.9 million, respectively, related to short-term leases. Total operating lease expense for the three and nine months ended September 30, 2018 was $7.5 million and $22.5 million, respectively.

~~Supplemental information related to leases is as follows (in thousands, except weighted-average data):~~

~~Future minimum rental payments under noncancelable operating leases as of December 31, 2018 were as follows (in thousands):~~

~~Maturities of lease liabilities as of September 30, 2019 were as follows (in thousands):~~

~~Operating lease assets, including prepaid rent balances related to the leases with GE, totaling $165.3 million are included~~recorded in “Other assets” in our unaudited Condensed Consolidated Balance Sheets ~~as of~~at September 30, ~~2019.~~2020.

AsPrepetition Restructuring Charges. We engaged financial and legal advisors to assist us in, among other things, analyzing various strategic alternatives to our capital structure, leading to the commencement of the Chapter 11 Cases in the Bankruptcy Court on April 26, 2020. Prior to the Petition Date, we incurred $7.4 million in legal and other professional advisor fees in connection with the consideration of restructuring alternatives, including the preparation for filing of the Chapter 11 Cases and related matters. We have reported these amounts in “Restructuring and separation costs” in our unaudited Condensed Consolidated Statements of Operations for the three and nine months ended September 30, ~~2019,~~2020.

Reduction in Force. In April 2020, we ~~had 2 additional~~initiated a plan to reduce the number of employees in our world-wide organization in an effort to restructure our business operations and lower operating ~~leases~~costs. During the three- and nine-month periods ended September 30, 2020, we incurred $0.4 million and $10.1 million, respectively, primarily for ~~mooring equipment to be used on~~severance and related costs associated with a reduction in personnel in our ~~rigs that had not yet commenced. The first agreement, which was entered into during~~corporate offices, warehouse facilities and certain of our international shorebase locations. We have reported these amounts in “Restructuring and separation costs” in our unaudited Condensed Consolidated Statements of Operations for the ~~first quarter of 2019~~three and commenced in October 2019, provides for fixed lease payments of approximately $12 million in the aggregate to be paid over a lease term of 9.5 years. The second agreement, which was entered into in the third quarter of 2019 and is expected to commence in Januarynine months ended September 30, 2020 ~~provides for fixed lease payments of approximately $5 million in the aggregate to be paid over a lease term of five years.~~.

Although we provide contract drilling services with different types of offshore drilling rigs and also provide such services in many geographic locations, we have aggregated these operations into 1 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.

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 September 30, ~~2019,~~2020, our active drilling rigs were located offshore 34 countries in addition to the United ~~States.~~States, including the Ocean Monarch, which is earning a standby rate in Malaysia awaiting clearance to begin operations in Myanmar waters. Revenues by geographic area are presented by attributing revenues to the individual country ~~or areas~~ where the services were ~~performed and, unless otherwise noted, reflect earnings attributable to our floater rigs (drillships and semisubmersibles).~~performed.

The following tables provide information about disaggregated revenue by ~~primary geographical market~~country (in thousands):

Three Months Ended September 30, 2018

Total
Contract
Drilling
Revenues

Revenues
Related to
Reimbursable
Expenses

Total

United States

$
155,695

$
1,916

$
157,611

South America

49,410

(32
)

49,378

Europe

30,809

1,996

32,805

Australia/Asia

44,777

1,751

46,528

Total

$
280,691

$
5,631

$
286,322

	Three Months Ended September 30, 2020
	Total Contract Drilling Revenues		Revenues Related to Reimbursable Expenses		Total
United States	$	57,523	$	2,569	$	60,092
Brazil		25,774		16		25,790
United Kingdom		25,178		2,198		27,376
Australia		16,279		2,570		18,849
Malaysia		4,591		1,559		6,150
Total	$	129,345	$	8,912	$	138,257

Nine Months Ended September 30, 2018

Total
Contract
Drilling
Revenues

Revenues
Related to
Reimbursable
Expenses

Total

United States⁽¹⁾

$
482,337

$
5,224

$
487,561

South America

129,966

(31
)

129,935

Europe

60,938

5,116

66,054

Australia/Asia

160,729

6,414

167,143

Total

$
833,970

$
16,723

$
850,693

	Nine Months Ended September 30, 2020
	Total Contract Drilling Revenues		Revenues Related to Reimbursable Expenses			Total
United States	$	244,578	$	8,998		$	253,576
Brazil		145,921		(24	)		145,897
United Kingdom		86,949		7,075			94,024
Australia		49,663		10,682			60,345
Malaysia		8,737		3,051			11,788
Total	$	535,848	$	29,782		$	565,630

~~In June 2019,~~On March 27, 2020, the ~~Internal Revenue Service issued final regulations with respect to the calculation~~President of the ~~toll charge associated with~~United States signed into law the ~~deemed repatriation~~Coronavirus Aid, Relief and Economic Security Act (or the CARES Act). The CARES Act allows a carryback of ~~previously deferred earnings~~net operating losses generated in 2018, 2019 and 2020 to each of ~~our non-U.S. subsidiaries, or Transition Tax, in response to~~ the ~~Tax Cuts and Jobs Act enacted in 2017. Based on~~five preceding taxable years. As a result of the ~~new regulations,~~carryback, we

~~recorded~~ recognized a ~~net~~ tax benefit of ~~$14.2~~$9.7 million induring the ~~second~~first quarter of ~~2019, primarily~~2020 due to ~~reverse~~a partial release of a previously ~~recorded uncertain~~recognized valuation allowance and tax ~~position related to the Transition Tax.~~ rate change.

Several of our rigs are owned by Swiss branches of entities incorporated in the United Kingdom that have historically been taxed under a special tax regime pursuant to Swiss corporate income tax rules. On September 3, 2019, the Swiss federal government, along with the Canton of Zug, enacted tax legislation, which we refer to as “Swiss Tax Reform”, effective as of January 1, 2020. Swiss Tax Reform significantly changed Swiss corporate income tax rules by, among other things, abolishing special tax regimes. The ~~legislation also provides transition rules under which companies can maintain their current basis of taxation through January 1, 2022.~~

The abolition of special tax regimes will require us to determine our Swiss tax liability on a net income basis beginning on January 1, 2022, thus also requiring deferred taxes to be computed on the difference between the Swiss tax basis and U.S. GAAP basis of certain items, including property, plant and equipment. There are still many uncertainties in the application of Swiss Tax Reform, including the values to be used to measure depreciable property. Therefore, we have recorded an $85.0 million deferred tax asset for the difference in basis of certain of our rigs between Swiss tax and U.S. GAAP, fully offset by a reserve for an uncertain tax position.

~~As further clarification is issued by the Swiss tax authorities, deferred tax balances and the reserve for uncertain tax positions~~ Chapter 11 Cases may ~~need to be adjusted. The potential changes could~~ have a material ~~effect~~impact on our ~~consolidated financial statements.~~tax attributes, the full extent of which will not be known until a plan of reorganization is approved by the Bankruptcy Court. Cancellation of indebtedness income resulting from the Chapter 11 Cases may reduce our tax attributes including, but not limited to, net operating loss carryforwards, foreign tax credits and depreciable tax basis of our offshore drilling rigs. In addition, the utilization of any remaining tax attributes could potentially be limited in future periods should the plan of reorganization result in an ownership change under Internal Revenue Code Section 382.

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 Part II of this ~~report and~~report; our audited consolidated financial statements (including the notes thereto), Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Item 1A, ~~“Risk~~��Risk Factors” included in our Annual Report on Form ~~10-K~~10-K/A for the year ended December 31, ~~2018.~~2019; and Item 1A, “Risk Factors” included in Part II of our Quarterly Reports on Form 10-Q for the quarters ended March 31, 2020 and June 30, 2020. References to “Diamond Offshore,” “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 1513 floater rigs (four drillships and 119 semisubmersibles), including two cold-stacked semisubmersible rigs, the Ocean GreatWhite and Ocean Valiant. We are in the process of ~~which two rigs are currently cold-stacked.~~reactivating the Ocean Onyx for a contract with Beach Energy, expected to commence in the first quarter of 2021. The Ocean ~~Confidence~~America~~, an additional cold-stacked semisubmersible rig, is~~ and Ocean Rover, which were cold stacked in 2015 and 2016, respectively, are being marketed for sale and ~~has~~have been excluded from our ~~active~~current rig fleet. ~~The reactivation~~See “– Market Overview.”

On April 26, 2020 (or the Petition Date), Diamond Offshore Drilling, Inc. (or the Company) and ~~upgrade~~certain of its direct and indirect subsidiaries (which we refer to together with the Company, as the Debtors) filed voluntary petitions (or the Chapter 11 Cases) for relief under chapter 11 (or Chapter 11) of title 11 of the United States Code (or the Bankruptcy Code) in the United States Bankruptcy Court for the Southern District of Texas (or the Bankruptcy Court). ~~Ocean Onyx~~ ~~is nearly complete,~~As of the date of this report, the Debtors have not emerged from bankruptcy and ~~we expect~~no plan of reorganization or restructuring support agreement has been filed with the ~~rig~~Bankruptcy Court. Negotiations between the various parties to ~~begin operating under contract during~~ the ~~first quarter~~Chapter 11 Cases are ongoing.

See Note 2 “Chapter 11 Proceedings” to our unaudited condensed consolidated financial statements included in Item 1 of ~~2020.~~Part I of this report and “– Liquidity and Capital Resources.”

AtThe offshore contract drilling market continues to be severely challenged with an oversupply of rigs, in addition to continued depressed commodity prices and the uncertainty around long-lead drilling projects.

The COVID-19 outbreak and measures to mitigate the spread of the virus that occurred in most parts of the world contributed to a dramatic fall in demand for oil during the first three quarters of 2020. Economies in parts of the world have now reopened or are in various stages of reopening, while economies in other parts of the globe remain in various stages of lockdown. Some geographic areas are also experiencing a resurgence of COVID-19 cases and are re-implementing strategies to contain the spread of the virus. Partial easing of lockdowns in some areas has resulted in a gradual increase in demand for oil and gas. In addition, commodity prices have risen modestly since the start of the second quarter of 2020, primarily due to an agreement reached by the Organization of Petroleum Exporting Countries and other oil producing nations on oil production quotas. As of the date of this report, the price for Brent crude oil was in the high $30-per-barrel range. Despite the modest recovery in commodity price since the first quarter of 2020, some analysts expect downward pressure on oil prices to persist for the remainder of 2020 and could continue for the foreseeable future.

Many exploration and production companies, including some of our customers, made significant reductions in their 2020 capital spending programs earlier in the year in response to low commodity prices and uncertain global demand. As a result, some offshore rigs were released early from drilling programs or have had their contracts terminated, while other programs have been paused in response to the need for COVID-19 containment. Given the uncertainty around COVID-19 and other macroeconomic factors, many customers continue to defer capital spending.

In April 2020, we received a purported notice of termination by a subsidiary of Beach Energy Limited, or Beach, of its contract for the Ocean Onyx. During the third quarter of 2020, we entered into a settlement agreement

and new drilling contract with Beach. Operations under the new contract are expected to commence in the first quarter of 2021.

Global floater contracted utilization was approximately 61% at the end of the third quarter of ~~2019, the average price for Brent crude oil was at the $60-per-barrel level. Industry-wide floater utilization was approximately 66%~~2020 with 134 contracted rigs, based on an industry ~~analyst reports,~~report. There are also 26 floater rigs on order that are scheduled for delivery between 2020 and 2022, only two of which ~~was relatively unchanged from~~have been contracted for future work. Another 15 floater contract rollovers are expected to occur in the ~~previous quarter but~~final months of 2020, increasing rig supply and competition in an increase from approximately 58% for the comparable quarter of 2018. During 2019, there has been a slight improvement in average dayrates in some geographic markets; however, dayrates remain low compared to previous periods, as the increase in oil prices from earlier lows has not resulted in significantly higher dayrates at a sustained or consistent level. Somealready depressed market. Global rig attrition is projected by industry analysts ~~indicate that, based on historical data, utilization rates will have~~ to increase as a market recovery is not expected in the near term. During this time, drilling contractors may elect to forego upcoming special surveys of rigs rolling off contract with no future work, resulting in the ~~80%-range before pricing power shifts to~~cold stacking or ultimate retirement of a rig. Historically, the longer a drilling ~~contractor from~~rig remains cold stacked, the ~~customer.~~cost of reactivation increases and the likelihood of reactivation decreases.

During the first ~~nine months~~quarter of ~~2019, the number~~2020, we recognized asset impairments aggregating $774.0 million to write down four of ~~contract tenders~~our semisubmersible rigs to their estimated fair values, including two semisubmersible rigs that are being marketed for ~~2020 and 2021 floater project commencements increased, primarily for work~~sale. If market fundamentals in the ~~North Sea~~offshore oil and ~~Australia markets~~. ~~Presently, many of these tenders have been limited~~gas industry continue to ~~single-well contracts, with options for~~deteriorate or a market recovery is further delayed, we may be required to recognize additional impairment charges in future ~~wells. Although some geographic areas appear to be improving, other markets show little or no sign of recovery at this time.~~

From a supply perspective, some industry analysts have reported a three-rig decrease in the global supply of floater rigs during the third quarter of 2019. However, the offshore contract drilling market remains oversupplied, providing for a challenging offshore drilling market in the near term.periods. As of the date of this report, ~~industry analysts report that there are approximately 80 stacked or uncontracted floaters and~~ ~~approximately 30 newbuild floaters currently under construction that are scheduled for delivery during the remainder~~we have two cold-stacked semisubmersible rigs, one of 2019 through 2022. Of these rigs under construction, some industry analysts report that only one rig is currently contracted for future work. In addition, during the next twelve months, approximately 70 contracted floaters are estimated to be rolling off their current contracts, which ~~will further add to the over-supply of floaters.~~has not been previously impaired.

As a result of these challenges, we and other offshore drillers are continuing to actively seek ways to drive efficiency, reduce non-productive time on rigs and provide technical innovation to customers. We anticipate that these efficiencies and innovations will result in the faster drilling and completion of wells, leading to lower overall well costs to the benefit of our customers.

~~See “– Contract Drilling Backlog”for future commitments of our rigs during 2019 through 2024.~~

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 will be different than the amounts and periods shown in the tables below due to various factors. Our utilization rates, which generally ~~approach~~have approached 92-98% during contracted periods, can be adversely impacted by downtime due to various operating factors including ~~but not limited~~effects of COVID-19 and efforts to mitigate the spread of the virus, weather conditions and unscheduled repairs and maintenance. Contract drilling backlog excludes revenues for mobilization, demobilization, contract preparation

and customer reimbursables. No revenue is generally earned during periods of downtime for regulatory surveys. 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 related to revenue expected to be recognized in the future related to unsatisfied performance obligations, which are presented in Note 23 “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 23 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 October 1, ~~2019 (based on information available at that time)~~2020 (and does not include any contracts signed after October 1, 2020 but prior to the date of this report), January 1, ~~2019~~2020 (the date reported in our Annual Report on Form ~~10-K~~10-K/A for the year ended December 31, ~~2018)~~2019), and October 1, 2019~~2018~~ (the date reported in our Quarterly Report on Form 10-Q for the quarter ended September 30, ~~2018~~2019) (in ~~thousands)~~millions).

The following table reflects the amount of revenue related to our contract drilling backlog by year as of October 1, ~~2019 (in thousands)~~2020 (in millions).

The following table reflects the percentage of rig days committed by year as of October 1, ~~2019.~~2020. 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, ~~but excluding rigs classified as held for sale,~~ multiplied by the number of days in a particular year).

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

Restructuring Costs. We expect to incur incremental costs of approximately $25.0 million to $30.0 million during the fourth quarter of 2020 for attorneys, financial advisors and other professionals in connection with the Chapter 11 Cases.

COVID-19 Pandemic. The most immediate impact and risks to our business as a result of the COVID-19 outbreak and efforts to mitigate the spread of the virus have been to the safety of our personnel, as well as travel restrictions that have challenged the ability to move personnel, equipment, supplies and service personnel to-and-from our drilling rigs. In some instances, we have asked our rig crews to quarantine in-country before offshore rotations, as well as to remain in country after their offshore rotation, resulting in incremental costs for salaries and other employee-related expenses such as meals and lodging. Our employee travel costs have also increased due to decreased passenger capacity on carriers, requiring additional trips to move personnel. In some cases, we incur freight surcharges to bring equipment and supplies to our rigs. We have also incurred additional costs to deep-clean facilities, for medical personnel and to purchase medical supplies and personal protective equipment.

With respect to protecting our crews and, thus, our rig operations, we have adopted COVID-19 testing requirements based on the regions in which our rigs are operating that primarily require testing of all personnel prior to an offshore rotation or travel from the U.S. to an international location. Additionally, for most of our rigs we have implemented the following health protocols once personnel are on board a rig:

In addition, the Ocean Monarch was previously expected to commence drilling operations in Myanmar in late March 2020. As a result of the COVID-19 pandemic and restrictions put in place by the Republic of the Union of Myanmar, the start of the drilling contract has been delayed until COVID-19 restrictions are eased and our customer has agreed to commence the drilling program. As of the date of this report, the Ocean Monarch is currently warm stacked in Johor Bahru, Malaysia where it is earning a standby rate intended to cover our daily operating costs while waiting to commence its contract. We expect the contract to commence in the fourth quarter of 2020.

During the three- and nine-month periods ended September 30, 2020, we incurred incremental costs of approximately $3.6 million and $8.7 million, respectively, related to the COVID-19 pandemic. As of the date of this report, we expect to incur similar types of costs during the remainder of 2020 but cannot predict the future financial impact of our response to the pandemic nor its duration in this fluid environment. As such, costs may be more than projected, perhaps by a material amount.

Regulatory Surveys and Planned Downtime. Our operating income is negatively impacted when we perform certain regulatory inspections, which we refer to as a special survey, that are due every five years for most of our rigs. The inspection interval for our North Sea rigs is two-and-one-half years. In addition, our operating income is negatively impacted 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. WeDuring the remainder of 2020, we expect to spend approximately ~~185~~120 days ~~during the fourth quarter of 2019~~ for upgrades, surveys, contract preparation and mobilization of rigs, which includes ~~an aggregate of~~ approximately 90 days for ~~the completion of upgrades,~~ reactivation ~~activities and contract preparation for the~~ ~~Ocean Onyx~~ ~~prior to its contract commencement, an aggregate of approximately 60 days for special surveys and rig upgrades for the~~ ~~Ocean BlackHornet~~ ~~and~~ ~~Ocean BlackRhino~~ ~~and an aggregate of approximately 35 days for mobilization~~ and contract preparation activities for ~~other rigs. In 2020, we expect to spend an additional 90 days for contract preparation for~~ the Ocean Onyx~~, an aggregate of~~ and approximately ~~240 days for upgrades for the~~ ~~Ocean BlackRhino~~ ~~and a special survey and upgrades for the~~ ~~Ocean BlackLion,~~ ~~approximately 60~~30 days for the mobilization of ~~and contract preparation for~~ the Ocean Monarch ~~prior~~and Ocean Apex related to ~~its contract in Myanmar and approximately 35 days for mobilizations of other rigs.~~their upcoming contracts. We can provide no assurance as to the exact timing and/or duration of downtime associated with regulatory inspections, upgrades, contract preparation, rig mobilizations and other shipyard projects. See “ – Contract Drilling Backlog.”

~~Regulatory Compliance~~. In May 2019, the U.S. Department of the Interior’s Bureau of Safety and Environmental Enforcement, which governs offshore drilling in the U.S. Outer Continental Shelf, or OCS, issued its final Well Control Rule on blowout preventer systems and well control regulations. The final Well Control Rule left 274 of the original 342 well control rule provisions unchanged, identified 68 provisions for revision and added 33 provisions to improve operations in the OCS. Based on our review of the final Well Control Rule, we do not believe that we will have any foreseeable material compliance issues and do not believe that any additional material equipment modifications will be required for our rigs currently working in the OCS.

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 $25.0 million per occurrence. We do not typically retain loss-of-hire insurance policies to cover our rigs.

In addition, we carry marine liability insurance covering certain legal liabilities, including coverage for certain personal injury claims, 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 policies our deductibles for marine liability coverage related to insurable events arising due to named windstorms in the U.S. Gulf of Mexico are $25.0 million for the first occurrence and vary in amounts ranging between $25.0 million and, if aggregate claims exceed certain thresholds, 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. Our deductibles for other marine liability coverage, including personal injury claims not related to named windstorms in the U.S. Gulf of Mexico, are $5.0 million for the first occurrence and vary in amounts ranging between $5.0 million and, if aggregate claims exceed certain thresholds, 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.

Our significant accounting policies are discussed in Note 1 of our notes to the audited consolidated financial statements included in our Annual Report on Form ~~10-K~~10-K/A for the year ended December 31, ~~2018. Effective January 1,~~2019.

~~2019, we adopted the Financial Accounting Standards Board Accounting Standards Update No. 2016-02,~~ ~~Leases~~ ~~(Topic 842), or ASU 2016-02, which, among other things, requires lessees to recognize a right of use asset and a lease liability for most leases. See Note 1 “General Information -~~ ~~Recently Adopted Accounting Pronouncements~~” and Note 9 “Leases and Lease Commitments” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report. There were no other material changes to these policies during the nine months ended September 30, 2019.

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. The following table presents these three key performance indicators and other comparative data relating to our revenues and operating expenses for the three-month and nine-month periods ended September 30, 2020 and 2019 (in thousands, except days, daily amounts and ~~2018~~percentages).

	Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			Three Months Ended September 30,						Nine Months Ended September 30,
	(In thousands, except days, daily amounts and percentages)												2020			2019			2020			2019
REVENUE-EARNING DAYS ⁽¹⁾		959			841			2,451			2,474			675			959			2,290			2,451
UTILIZATION ⁽²⁾		65	%		54	%		55	%		53	%		49	%		65	%		55	%		55	%
AVERAGE DAILY REVENUE ⁽³⁾	$	252,600		$	333,400		$	275,900		$	333,600		$	191,800		$	252,600		$	234,000		$	275,900

REVENUE RELATED TO CONTRACT DRILLING SERVICES	$	242,315		$	280,691		$	676,284		$	833,970		$	129,345		$	242,315		$	535,848		$	676,284
REVENUE RELATED TO REIMBURSABLE EXPENSES		11,705			5,631			27,984			16,723			8,912			11,705			29,782			27,984
TOTAL REVENUES	$	254,020		$	286,322		$	704,268		$	850,693		$	138,257		$	254,020		$	565,630		$	704,268
CONTRACT DRILLING EXPENSE, EXCLUDING DEPRECIATION	$	201,568		$	188,456		$	593,779		$	562,466		$	130,921		$	201,568		$	481,376		$	593,779
REIMBURSABLE EXPENSES	$	11,423		$	5,574		$	27,479		$	16,458		$	8,578		$	11,423		$	27,997		$	27,479
OPERATING LOSS
Contract drilling services, net	$	40,747		$	92,235		$	82,505		$	271,504		$	(1,576	)	$	40,747		$	54,472		$	82,505
Reimbursable expenses, net		282			57			505			265			334			282			1,785			505
Depreciation		(88,693	)		(81,884	)		(263,844	)		(245,534	)		(75,330	)		(88,693	)		(243,208	)		(263,844	)
General and administrative expense		(18,830	)		(33,308	)		(51,436	)		(70,057	)		(12,781	)		(18,830	)		(44,827	)		(51,436	)
Impairment of assets		-			-			-			(27,225	)		—			—			(774,028	)		—
Restructuring and separation costs		-			(649	)		-			(4,925	)		(344	)		—			(17,463	)		—
(Loss) gain on disposition of assets		(6,340	)		506			(1,191	)		1,066
Gain (loss) on disposition of assets														479			(6,340	)		4,132			(1,191	)
Total Operating Loss	$	(72,834	)	$	(23,043	)	$	(233,461	)	$	(74,906	)	$	(89,218	)	$	(72,834	)	$	(1,019,137	)	$	(233,461	)
Other income (expense):
Interest income		1,317			2,364			5,664			6,001			22			1,317			520			5,664
Interest expense, net of amounts capitalized		(31,098	)		(34,293	)		(92,182	)		(92,196	)		(98	)		(31,098	)		(42,753	)		(92,182	)
Foreign currency transaction (loss) gain		(77	)		(743	)		(1,883	)		115
Foreign currency transaction loss														(661	)		(77	)		(1,458	)		(1,883	)
Reorganization items, net														(8,663	)		—			(62,640	)		—
Other, net		82			(179	)		520			664			107			82			349			520
Loss before income tax benefit		(102,610	)		(55,894	)		(321,342	)		(160,322	)
Income tax benefit		7,482			4,782			38,898			59,257
Loss before income tax (expense) benefit														(98,511	)		(102,610	)		(1,125,119	)		(321,342	)
Income tax (expense) benefit														(95	)		7,482			19,753			38,898
NET LOSS	$	(95,128	)	$	(51,112	)	$	(282,444	)	$	(101,065	)	$	(98,606	)	$	(95,128	)	$	(1,105,366	)	$	(282,444	)

Net results for the third quarter of ~~2019 decreased $44.0 million~~2020 were essentially flat compared to the third quarter of ~~2018, reflecting~~2019, decreasing only $3.5 million. The negative impacts of lower margins from our contract drilling services ~~primarily driven~~($42.3 million) and reorganization costs ($8.7 million) during the third quarter of 2020 were partially offset by lower ~~contract~~other expenses, net ($47.5 million), including a decrease in general and administrative costs, depreciation and interest expense.

Contract Drilling Revenue. Contract drilling revenue ~~combined with an increase in contract drilling expenses. Contract drilling services contributed operating income of $40.7~~decreased $113.0 million during the third quarter of 2019, compared to operating income of $92.2 million in the third quarter of 2018. Our results for the third quarter of 2019 were also negatively impacted by a net pre-tax loss of $6.3 million on the disposal of certain property and equipment during the quarter and by higher depreciation expense of $6.8 million, primarily due to capital expenditures made since the latter part of 2018. These unfavorable impacts to our net results were partially offset by a decrease in general and administrative expense of $14.5 million and an incremental tax benefit of $2.7 million recognized during the third quarter of 2019.

~~Operating Results.~~ ~~Contract drilling revenue decreased $38.4 million during the third quarter of 2019~~2020 compared to the third quarter of ~~2018,~~2019, primarily due to the effect of 284 fewer R-E days ($71.9 million) and lower average daily revenue earned ($~~77.5 million), partially offset by the effect of 118 incremental revenue-earning days ($39.1~~41.1 million). ~~The decrease in average daily revenue reflects the impact of lower dayrates earned under contracts that commenced after the third quarter of 2018, the completion of a long-term contract for the~~ ~~Ocean BlackHornet~~ ~~in July 2019, which was at a significantly higher dayrate than available in the current market, and a reduction in upgrade and mobilization revenue recognized during the quarter. Revenue-earning~~R-E days ~~increased,~~decreased compared to the third quarter of ~~2018,~~2019, primarily due to fewer ~~non-productive~~R-E days ~~(138~~related to the cold-stacked Ocean Valiant and Ocean GreatWhite (an aggregate 184 fewer R-E days) and incremental downtime attributable to the warm stacking of rigs between contracts (209 fewer R-E days), partially offset by incremental R-E days due to less downtime for planned shipyard projects and mobilization of rigs ~~(72~~(83 additional R-E days)~~, partially offset by the unfavorable impact of fewer revenue-earning days~~ and less unplanned downtime for rig repairs and maintenance (26 additional R-E days). The decrease in average daily revenue was primarily related to the Ocean ~~Guardian~~BlackHornet and Ocean BlackLion both starting new contracts in 2020 at significantly lower dayrates than the rigs’ previous contracts and the Ocean Monarch, which ~~operated~~earned a reduced standby rate throughout the third quarter of ~~2018 but was sold in 2019 (92 days).~~2020 due to COVID-19 related delays.

Contract Drilling Expense, Excluding Depreciation. Contract drilling expense, excluding depreciation, ~~increased $13.1~~decreased $70.6 million during the third quarter of ~~2019~~2020 compared to the third quarter of ~~2018, primarily due to higher~~2019, as a result of lower amortization of previously deferred contract preparation and mobilization costs ($18.3 million), combined with lower costs for repairs, maintenance and ~~maintenance~~inspections, ($~~5.3~~18.0 million), ~~overhead and shorebase support ($4.9 million),~~ labor and personnel ($~~1.9~~9.7 million), equipment ~~rental~~rentals ($~~1.6~~5.2 million) and other rig operating costs ($~~2.6~~9.3 million)~~. In addition,~~, primarily due to the stacking of rigs discussed above. The reduction in rig operating expense during the third quarter of ~~2019, we deferred fewer contract~~2020 also reflected a reduction in shorebase and overhead costs ~~associated with contract preparation activities, including mobilization~~as a result of ~~rigs, than during~~recent cost cutting initiatives ($10.1 million).

Depreciation Expense. Depreciation expense for the third quarter of ~~2018 ($8.3 million). These cost increases were partially offset by the absence of costs for the~~ ~~Ocean Guardian~~ ~~($6.3 million) and a reduction in fuel and moving costs ($5.2 million).~~

~~General and administrative expense~~2020 decreased ~~$14.5~~$13.4 million compared to the third quarter of ~~2018,~~2019. The reduction in depreciation expense primarily ~~due~~related to ~~the absence of~~ a ~~$17.5 million charge~~lower depreciable asset base in the third quarter of ~~2018 for settlement~~2020 due to asset impairments recognized during the first quarter of 2020.

Interest Expense. Upon filing the Chapter 11 Cases on April 26, 2020, we ceased accruing interest expense on our senior unsecured debt and revolving credit agreement, or Credit Agreement, which we entered into on October 2, 2018. As a ~~legal claim,~~result, in the third quarter of 2020, we did not record contractual interest expense related to our senior notes ($28.3 million) and outstanding borrowings under the Credit Agreement ($9.5 million).

Reorganization Items, net. In the third quarter of 2020, we recognized $8.7 million in expenses and other net losses directly related to the Chapter 11 Cases, primarily consisting of professional fees ($18.7 million), partially offset by ~~an adjustment in the 2019 period~~net gains related to ~~a long-term incentive compensation plan.~~vendor settlements and purchase order cancellations ($10.0 million). See Note 2 to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report.

Income Tax (Expense) Benefit. We recorded a net income tax expense of $(0.1) million (-0.1% effective tax rate) for the third quarter of 2020, compared to an income tax benefit of $7.5 million (7.3% effective tax rate) for the ~~third quarter of 2019, compared to an income tax benefit of $4.8 million (8.6% effective tax rate) for the~~ same quarter of ~~2018.~~2019. The ~~difference~~decrease in the ~~amount of~~effective tax ~~benefit recognized between the periods~~rate was ~~in large part~~primarily due to ~~the~~an increase in valuation allowance for tax attributes that are not likely to be realized and our mix of ~~our~~ domestic and international pre-tax ~~earnings~~profits and ~~losses for the periods.~~losses.

~~Net~~Our net results for the first nine months of ~~2019~~2020 decreased ~~$181.4~~$822.9 million compared to the same period of ~~2018, reflecting~~2019, primarily due to the impairment of assets in the first quarter of 2020 ($774.0 million), recognition of reorganization and restructuring costs ($80.1 million), lower margins earned from our contract drilling services ~~primarily driven~~($28.0 million) and higher income tax expense ($19.1 million), partially offset by lower ~~contract drilling revenue.~~ other expenses, net ($78.3 million), including a decrease in general and administrative costs, depreciation and interest expense.

Contract Drilling Revenue. Contract drilling ~~services contributed operating income of $82.5~~revenue decreased $140.4 million during the first nine months of 2019, compared to $271.5 million in the first nine months of 2018. Our results for the first nine months of 2019 were also negatively impacted by higher depreciation expense of $18.3 million, primarily due to capital expenditures and the completion of software implementation projects in 2019, and a lower income tax benefit recognized ($20.4 million), compared to the prior year period. These unfavorable impacts to our net results were partially offset by a reduction in general and

~~administrative expense ($18.6 million) in the first nine months of 2019 and the absence of impairment and restructuring charges recorded in the 2018 period.~~

~~Operating Results.~~ ~~Contract drilling revenue decreased $157.7 million during the first nine months of 2019~~2020 compared to the same period of ~~2018,~~2019, primarily due to lower average daily revenue earned ($~~141.4~~96.0 million)~~, the effect of 23~~ and 161 fewer ~~revenue-earning~~R-E days ($~~7.9~~44.4 million) ~~and the absence of $8.4 million~~. The decrease in ~~loss-of-hire insurance proceeds recognized during the 2018 period. Comparing the two periods,~~ average daily revenue ~~decreased~~was primarily due to both the Ocean BlackHornet and Ocean BlackLion both starting new contracts in 2020 at significantly lower dayrates ~~earned by some of our rigs as a result of renegotiating certain existing~~than the rigs’ previous contracts ~~during 2018~~ and ~~a lower dayrate earned by~~ the Ocean ~~GreatWhite~~Monarch, which ~~commenced operations under~~earned a reduced standby rate during the second and third quarters of 2020 due to COVID-19 related delays R-E days decreased, compared to the first nine months of 2019, primarily due to cold stacking the Ocean Valiant and Ocean GreatWhite (an aggregate 392 fewer R-E days) and incremental downtime attributable to the warm stacking of rigs between contracts (237 fewer R-E days), partially offset by incremental R-E days for the Ocean Endeavor (172 additional R-E days), which was reactivated for a new contract that commenced during the second quarter of 2019, less downtime for planned shipyard projects and mobilization of rigs (204 additional R-E days) and less unplanned downtime for rig repairs and maintenance (92 additional R-E days). The decline in revenues during the ~~U.K.~~first nine months of 2020 was partially offset by revenue recognized during the first quarter of ~~2019.~~2020 related to the reimbursement of withholding taxes related to one of our rigs in Brazil ($8.8 million).

Contract Drilling Expense, Excluding Depreciation. Contract drilling expense, excluding depreciation, ~~increased $31.3~~decreased $112.4 million during the first nine months of ~~2019~~2020 compared to the same period of ~~2018, primarily~~2019, primarily due to ~~incremental~~lower amortization of previously deferred contract preparation and mobilization costs ($~~30.0~~67.6 million), combined with ~~increased~~lower costs for ~~our current floater fleet for~~ repairs, maintenance and inspections ($27.8 million), labor and personnel ($~~8.7~~5.9 million)~~, repairs and maintenance ($9.2 million), equipment rental ($5.1 million), catering ($2.3 million) and overhead, shorebase support~~ and other rig costs ($~~4.8~~11.3 million)~~. These increases were partially offset by reduced costs for the previously-owned~~ , ~~Ocean Guardian~~ ~~($20.2 million) and lower fuel costs ($8.6 million) for our current fleet.~~

~~General and administrative expense decreased $18.6 million,~~ primarily ~~due~~related to the ~~absence~~stacking of ~~a $17.5 million charge recorded in the third quarter of 2018 for settlement of a legal claim.~~

~~Restructuring and Separation Costs.~~ rigs previously discussed~~In late 2017, our management approved and initiated a plan to restructure our worldwide operations, which also included a~~. The overall reduction in ~~workforce at our corporate facilities and onshore bases. During~~rig operating expense during the first nine months of ~~2018, we recognized $4.9 million~~2020 also reflecteda reduction in shorebase and overhead costs related to restructuring ~~and~~ efforts ($16.6 million) in 2020. These cost reductions were partially offset by an increase in other ~~employee separation related~~rig moving costs, ~~pursuant to this plan. Restructuring activities associated with the plan were substantially completed in 2018.~~including fuel ($16.8 million).

Impairment of Assets. During the first ~~nine months~~quarter of ~~2018,~~ 2020, we ~~recorded an~~evaluated five of our drilling rigs with indicators of impairment ~~loss~~ at that time and determined that the carrying values of ~~$27.2 million to recognize a reduction in fair value (less costs to sell)~~four of the ~~Ocean Scepter~~,rigs were impaired. As a ~~jack-up rig that was sold in July 2018.~~ result, we recognized an aggregate impairment charge of $774.0 million during the first quarter of 2020. See ~~Note 3 “Impairment of Assets”~~Notes 4 and 7 to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report.

Restructuring and Separation Costs. Prior to the Petition Date, we incurred $7.4 million in legal and other professional advisor fees in connection with the consideration of restructuring alternatives, including the preparation for filing of the Chapter 11 Cases and related matters. Also, during 2020, we initiated a plan to reduce the number of employees in our world-wide organization in an effort to restructure our business operations and lower operating costs. As a result of this initiative, we incurred costs of $10.1 million during the first nine months of 2020, primarily for severance and related costs associated with a reduction in personnel in our corporate offices, warehouse facilities and certain of our international shorebase locations. See Note 11 to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report.

Depreciation Expense. Depreciation expense for the first nine months of 2020 decreased $20.6 million compared to the same period of 2019. The reduction in depreciation expense was primarily due to a lower depreciable asset base in 2020 as a result of asset impairments recognized during the first quarter of 2020.

Interest Expense. We ceased accruing interest expense on our senior unsecured debt and amounts outstanding under the Credit Agreement upon filing the Chapter 11 Cases on April 26, 2020. As a result, we did not record $48.5 million and $13.9 million of contractual interest expense since that time related to our senior notes and Credit Agreement, respectively.

Reorganization Items, net. We recognized $62.6 million in expenses and other net losses directly related to the Chapter 11 Cases in the first nine months of 2020, primarily consisting of the write-off of debt issuance costs ($27.5 million) and professional fees ($39.3 million), offset by net gains related to vendor settlements and purchase order cancellations ($4.2 million). See Note 2 to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report.

Income Tax (Expense) Benefit. We recorded a net income tax benefit of $19.8 million (1.8% effective tax rate) for the first nine months of 2020, compared to an income tax benefit of $38.9 million (12.1% effective tax rate) for the ~~first nine months of 2019, compared to an income tax benefit of $59.3 million (37% effective tax rate) for the~~ same period of 2018. Income tax benefit for the 2018 period included a tax benefit of $43.3 million due to the reversal of an uncertain tax position related to the toll charge associated with the deemed repatriation of previously deferred earnings of our non-U.S. subsidiaries, or Transition Tax, under the Tax Cuts and Jobs Act enacted in 2017, or tax Reform Act, as a result of further guidance issued by the Internal Revenue Service, or IRS. This additional guidance clarified certain of our tax positions taken and, consequently, allowed us to reverse the previously recognized liability.2019. Income tax benefit for the 2019 period included a net $14.2 million income tax benefit ~~of $14.2 million~~ associated with the reduction in our estimate of our ~~Transition Tax~~transition tax liability pursuant to final regulations issued by the ~~IRS~~Internal Revenue Service in June ~~2019~~. 2019. On March 27, 2020, the President of the United States signed into law the Coronavirus Aid, Relief and Economic Security Act, or the CARES Act. The CARES Act allows a carryback of net

operating losses generated in 2018, 2019 and 2020 to each of the five preceding taxable years. As a result of the carryback, we recognized a tax ~~adjustments, the difference~~benefit of $9.7 million in the ~~amount~~first quarter of ~~income tax benefit recognized in the 2019 period, compared to the same period of 2018, was in large part~~2020 due to ~~the mix~~a partial release of ~~our domestic~~a previously recognized valuation allowance and ~~international pre-tax earnings and losses for the periods.~~tax rate change.

Although we anticipate that the Chapter 11 Cases will help address our liquidity concerns, uncertainty remains over the Bankruptcy Court's approval of a plan of reorganization, and therefore substantial doubt exists over our ability to continue as a going concern at this time. Financial information in this report has been prepared on the basis that we will continue as a going concern, which presumes that we will be able to realize our assets and discharge our liabilities in the normal course of business as they come due. Financial information in this report does not reflect the adjustments to the carrying values of assets and liabilities and the reported expenses and balance sheet classifications that would be necessary if we were unable to realize our assets and settle our liabilities as a going concern in the normal course of operations. Such adjustments could be material. Our long-term liquidity requirements, the adequacy of capital resources and ability to continue as a going concern are difficult to predict at this time and ultimately cannot be determined until a Chapter 11 plan has been confirmed, if at all, by the Bankruptcy Court. If our future sources of liquidity are insufficient, we could face substantial liquidity constraints and be unable to continue as a going concern and would likely be required to significantly reduce, delay or eliminate capital expenditures, implement further cost reductions, or seek other financing alternatives.

We have ~~principally~~historically relied on our cash flows from operations and cash reserves to meet our liquidity ~~needs. We have also utilized borrowings under~~needs, which primarily include the servicing of our ~~credit agreements, which currently provide for maximum borrowings of up to $1.2 billion, all of which was available to us~~debt repayments and interest payments, as ~~of October 25, 2019. In addition,~~well as funding our working capital requirements and capital expenditures. As of October 1, ~~2019,~~2020, our contractual backlog was ~~$1.8~~$1.2 billion, of which ~~$0.2~~$0.1 billion is expected to be realized during the fourth quarter of ~~2019.~~2020. Also, during the fourth quarter of ~~2019,~~2020, we expect to receive aan approximately $~~30.0~~25.0 million payment from a customer for ~~an unfulfilled~~a gross margin commitment pursuant to terms of an existing ~~contract.~~contract if the commitment is not satisfied by the signing of a new contract commencing in 2020. At September 30, ~~2019,~~2020, we had cash available for current operations of ~~$209.1~~$422.7 million.

~~Our worldwide~~ ~~earnings~~ and cash balances are available to finance both our domestic and foreign activities. We record the withholding income tax impact, if any, associated with the potential distribution of earnings of our foreign subsidiaries; however, we have not provided income tax on the outside basis difference of our international subsidiaries as management does not intend to dispose of these subsidiaries. We expect to utilize existing structuring alternatives to mitigate any potential liability should a disposition take place.

We have historically invested a significant portion of our cash flows in the enhancement of our drilling fleet. The amount of cash required to meet our capital commitments is determined by evaluating the need to upgrade our rigs to meet specific customer requirements and our ongoing rig equipment enhancement/replacement programs. We make periodic assessments of our capital spending programs based on current and expected industry conditions and make adjustments to them if required.

Based on our cash available and contract drilling backlog, we believe our 2019 capital spending and debt service requirements will be funded from our cash and cash equivalents, future operating cash flows and borrowings under our credit agreements, as needed. We expect, based on our current forecast, to utilize a portion of the availability under our credit agreements, commencing in the first half of 2020, to meet our short-term liquidity requirements. See “– Sources and Uses of Cash – ~~Rig Reactivation, Upgrades and Other Capital Expenditures~~.”

We may, from time to time, issue debt or equity securities, or a combination thereof, to finance capital expenditures, the acquisition of assets and businesses or for general corporate purposes. We have an effective automatic shelf registration statement under which we may publicly issue debt, equity or hybrid securities. Our ability to access the capital markets by issuing debt or equity securities will be dependent on our results of operations, our financial condition, credit ratings, market conditions and other factors beyond our control at the time we seek such access.

~~During the nine-month period ended September 30, 2019,~~Our operating activities provided net cash ~~usage for operating activities and capital expenditures was $14.2~~of $7.4 million ~~and $249.8 million, respectively.~~during the first nine months of 2020. Our ~~primary~~other sources of cash during the same period were ~~$303.0 million in proceeds from maturities of marketable securities, net of purchases,~~borrowings under the Credit Agreement ($436.0 million) and proceeds from the ~~disposition of assets, including $15.0 million from the sale~~sales of the Ocean ~~Guardian~~ Confidence ($4.6 million) and Trinidad bonds ($5.9 million). See Note 5 to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report. We used cash aggregating $162.6 million for capital expenditures during the ~~second quarter~~first nine months of ~~2019.~~2020.

The principal and interest under the Credit Agreement became immediately due and payable upon filing of the Chapter 11 Cases, which constituted an event of default under the Credit Agreement. Also, as a result of the filing of the Chapter 11 Cases, the commitments under the Credit Agreement were reduced to the amount of borrowings outstanding plus the value of a financial letter of credit issued in January 2020. See Note 9 “Credit Agreements” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report.

Cash Flow from Operations. Cash flow from operations for the ~~nine-month period ended September 30, 2019 decreased $203.0~~first nine months of 2020 increased $21.7 million compared to the ~~nine-month~~same period ~~ended September 30, 2018,~~of 2019, primarily due to lower ~~cash receipts for contract drilling services ($205.5 million) and higher income tax payments,~~ net ~~of refunds, primarily in our foreign tax jurisdictions ($14.7 million). Incremental cash used for operations during the 2019 period was partially offset by a net decrease in~~ cash expenditures ~~related to~~for contract drilling, shorebase support and general and administrative costs in 2020 compared to 2019 ($~~17.2~~46.0 million) and the receipt of cash income tax refunds, net of payments ($31.2 million) in the first nine months of 2020 compared to net cash taxes paid ($13.2 million) during the first nine months of 2019. Sources of operating cash flow during the first nine months of 2020 were partially offset by lower cash receipts for contract drilling services ($50.4 million), combined with collateral deposits made in support of certain outstanding surety and other bonds and letters of credit ($18.3 million).

~~Rig Reactivation,~~ Upgrades and Other Capital Expenditures. As of the date of this report, we expect cash capital expenditures for the ~~final quarter~~last three months of ~~2019~~2020 to be approximately ~~$110~~$25 million to ~~$130~~$35 million for a total spend of approximately ~~$360~~$190 million to ~~$380~~$200 million in ~~2019. 2019 capital expenditures include~~2020. Planned spending ~~associated with projects under our capital maintenance and replacement programs, including~~for the remainder of 2020 includes equipment upgrades for

the Ocean ~~BlackHawk~~BlackLion ,and Ocean ~~BlackHornet~~Courage. ~~and~~ ~~Ocean Courage~~ ~~and other large shipyard projects. In addition, other specific projects for 2019 include (i) approximately $110 million in capitalized costs associated with the reactivation and upgrade of the~~ ~~Ocean Onyx~~ ~~and (ii) approximately $20 million associated with the reactivation of the~~ ~~Ocean Endeavor~~.

At September 30, ~~2019~~2020, we had no significant purchase obligations, except for those related to our direct rig operations, which arise during the normal course of business.

Other Obligations. As of September 30, ~~2019,~~2020, the total net unrecognized tax benefits related to uncertain tax positions was ~~$148.4~~$233.5 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.

We have various obligations corresponding to our lease arrangements. See Note 9 “Leases and Lease Commitments” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report.

On September 25, 2019, S&P Global Ratings, or S&P, downgraded our corporate and senior unsecured notes credit ratings to CCC+ from B. The rating outlook from S&P changed to stable from negative. Our current corporate credit rating from Moody’s Investor Services, or Moody’s, is B2 and our current senior unsecured notes credit rating from Moody’s is B3. The rating outlook from Moody’s is negative. These credit ratings are below investment grade and could raise our cost of financing. Consequently, we may not be able to issue additional debt in amounts and/or with terms that we consider to be reasonable. These ratings could limit our ability to pursue other business opportunities.

See Note 810 “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.

At September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, we had no off-balance sheet debt or other off-balance sheet arrangements.

See Note 1 “General Information – Recently Adopted Accounting Pronouncements” ~~and “~~ ~~– Accounting Pronouncements Not Yet Adopted”~~ to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report for a discussion of recently issued accounting pronouncements.

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:

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 under “Risk Factors” in Item 1A in our Annual Report on Form ~~10-K~~10-K/A for the year ended December 31, ~~2018~~2019, as supplemented and amended by Item 1A, “Risk ~~Factors,”~~Factors” included in Part II of ~~this report.~~our Quarterly Reports on Form 10-Q for the quarters ended March 31, 2020 and June 30, 2020.

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.

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. We monitor our sensitivity to interest rate risk by evaluating the change in the value of our financial assets and liabilities due to fluctuations in interest rates. The evaluation provides the sensitivity of the market value of our financial instruments to selected changes in market rates and prices which we believe are reasonably possible over a one-year period. This sensitivity analysis estimates the change in the market value of our

interest sensitive liabilities that were held on September 30, 2020 and December 31, 2019, due to instantaneous parallel shifts in the yield curve of 100 basis points, with all other variables held constant.

Our existing senior notes have been issued at fixed rates, and as such, interest expense would not be impacted by interest rate shifts. However, changes in market interest rates are reflected in the fair value of the debt. The impact of a 100-basis point increase in interest rates on fixed rate debt would result in a decrease in market value of $3.0 million and $89.7 million as of September 30, 2020 and December 31, 2019, respectively. A 100-basis point decrease would result in an increase in market value of $3.1 million and $102.0 million as of September 30, 2020 and December 31, 2019, respectively.

There were no other material changes in our market risk components for the nine months ended September 30, ~~2019.~~2020. See “Quantitative and Qualitative Disclosures About Market Risk” included in Item 7A of our Annual Report on Form ~~10-K~~10-K/A for the year ended December 31, ~~2018~~2019 for further information.

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 September 30, ~~2019.~~2020. Based on their participation in that evaluation, our CEO and CFO concluded that our disclosure controls and procedures were effective as of September 30, ~~2019.~~2020.

There were no changes in our internal control over financial reporting identified in connection with the foregoing evaluation that occurred during our third fiscal quarter of ~~2019~~2020 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Information related to certain legal proceedings is included in Note 810 “Commitments and Contingencies” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this ~~report.~~report, which is incorporated herein by reference. In addition, information related to the Chapter 11 Cases that we filed in the Bankruptcy Court on April 26, 2020 is included in Note 2 “Chapter 11 Proceedings – Chapter 11 Cases” to our unaudited condensed consolidated financial statements included in Item 1 of Part I of this report, which is incorporated herein by reference.

Our Annual Report on Form ~~10-K~~10-K/A for the year ended December 31, ~~2018 includes a detailed discussion of certain material risk factors facing our company. In~~2019, our Quarterly Report on Form 10-Q for the quarter ended March 31, 2020 and our Quarterly Report on Form 10-Q for the quarter ended June 30, 2020 include a detailed discussion of certain material risk factors facing our company. The risk factors included under Item 1A of our Annual Report on Form 10-K/a for the year ended December 31, 2019, ~~we restated one such~~as supplemented and amended by the risk ~~factor.~~ factors included under Item 1A of Part II of our Quarterly Reports on Form 10-Q for the quarters ended March 31, 2020 and June 30, 2020, are incorporated herein by reference. No material changes have been made to such risk factors as of September 30, ~~2019.~~2020.

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.

Title of each class		Trading Symbol		Name of each exchange on which registered
Common Stock, $0.01 par value per share		DODOFSQ		~~New York Stock Exchange~~OTC Pink Open Market

			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 Comprehensive ~~Income or~~ Loss	5
		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	2127

	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	3038

	ITEM 4.	Controls and Procedures	3039

PART II. OTHER INFORMATION			3140

	ITEM 1.	Legal Proceedings	3140

	ITEM 1A.	Risk Factors	3140

	ITEM 6.	Exhibits	3241

SIGNATURES			3342

	Three Months Ended			Nine Months Ended
	September 30, 2020
Professional fees	$	18,634		$	39,293
Write-off of debt issuance costs		—			27,552
Net gain on settlement with certain unsecured vendors		(9,971	)		(4,205	)
Total reorganization items, net	$	8,663		$	62,640

	September 30,
	2020
ASSETS
Current assets:
Cash and cash equivalents	$	407,222
Restricted cash		25,692
Accounts receivable		128,480
Less: allowance for credit losses		(175	)
Accounts receivable, net		128,305
Prepaid expenses and other current assets		49,577
Assets held for sale		1,000
Total current assets		611,796
Drilling and other property and equipment, net of
accumulated depreciation		4,232,543
Investments in non-debtor subsidiaries		2,458,447
Noncurrent deferred tax assets, net		31,356
Other assets		192,094
Total assets	$	7,526,236
LIABILITIES AND DEBTORS’ EQUITY
Current liabilities:
Accounts payable	$	28,993
Accrued liabilities		114,935
Taxes payable		26,062
Amounts payable to non-debtor subsidiaries		1,043,326
Total current liabilities		1,213,316
Note payable to non-debtor subsidiary		328,000
Other liabilities		45,157
Total liabilities not subject to compromise		1,586,473
Liabilities subject to compromise		2,653,655
Total debtors’ equity		3,286,108
Total liabilities and debtors’ equity	$	7,526,236

	Net Contract
	Balances
Contract assets at January 1, 2019	$	8,939
Contract liabilities at January 1, 2019		(20,526	)
Net balance at January 1, 2019		(11,587	)
Decrease due to amortization of revenue included in the beginning contract liability balance		5,385
Increase due to cash received, excluding amounts recognized as revenue during the period		(20,444	)
Increase due to revenue recognized during the period but contingent on future performance		3,537
Decrease due to transfer to receivables during the period		(2,796	)
Adjustments		(1,044	)
Net balance at September 30, 2019	$	(26,949	)
Contract assets at September 30, 2019	$	8,638
Contract liabilities at September 30, 2019		(35,587	)


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


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

Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

	Three Months Ended September 30, 2018
										Accumulated
					Additional					Other								Total
	Common Stock				Paid-In		Retained			Comprehensive			Treasury Stock					Stockholders’
	Shares		Amount		Capital		Earnings			Gains (Losses)			Shares		Amount			Equity
July 1, 2018		144,374,006	$	1,444	$	2,013,862	$	1,899,735		$	23			6,943,090	$	(204,334	)	$	3,710,730
Net loss		—		—		—		(51,112	)		—			—		—			(51,112	)
Stock-based compensation, net of tax		4,506		—		1,568		—			—			964		(20	)		1,548
Net loss on investments		—		—		—		—			(25	)		—		—			(25	)
Net loss on derivative financial instruments		—		—		—		—			(2	)		—		—			(2	)
September 30, 2018		144,378,512	$	1,444	$	2,015,430	$	1,848,623		$	(4	)		6,944,054	$	(204,354	)	$	3,661,139

	Nine Months Ended September 30, 2018
										Accumulated
					Additional					Other								Total
	Common Stock				Paid-In		Retained			Comprehensive			Treasury Stock					Stockholders’
	Shares		Amount		Capital		Earnings			Gains (Losses)			Shares		Amount			Equity
December 31, 2017		144,085,292	$	1,441	$	2,011,397	$	1,964,497		$	(5	)		6,857,510	$	(203,069	)	$	3,774,261
Impact of change in accounting principle		—		—		—		(14,812	)		—			—		—			(14,812	)
Adjusted balance at January 1, 2018		144,085,292	$	1,441	$	2,011,397	$	1,949,685		$	(5	)		6,857,510	$	(203,069	)	$	3,759,449
Net loss		—		—		—		(101,065	)		—			—		—			(101,065	)
Anti-dilution payments		—		—		—		3			—			—		—			3
Stock options exercised		3,773		—		—		—			—			—		—			—
Stock-based compensation, net of tax		289,447		3		4,033		—			—			86,544		(1,285	)		2,751
Net gain on investments		—		—		—		—			6			—		—			6
Net loss on derivative financial instruments		—		—		—		—			(5	)		—		—			(5	)
September 30, 2018		144,378,512	$	1,444	$	2,015,430	$	1,848,623		$	(4	)		6,944,054	$	(204,354	)	$	3,661,139

	September 30,
	2020
Debt subject to compromise:
Borrowings under credit facility	$	436,000
3.45% Senior Notes due 2023		250,000
7.875% Senior Notes due 2025		500,000
5.70% Senior Notes due 2039		500,000
4.875% Senior Notes due 2043		750,000
Lease liabilities		140,580
Accrued interest		47,636
Accounts payable		19,912
Other accrued liabilities		5,306
Other liabilities		4,221
Total liabilities subject to compromise	$	2,653,655

	Net Contract
	Balances
Contract assets at January 1, 2020	$	6,314
Contract liabilities at January 1, 2020		(48,104	)
Net balance at January 1, 2020		(41,790	)
Decrease due to amortization of revenue included in the beginning contract liability balance		31,016
Increase due to cash received, excluding amounts recognized as revenue during the period		(40,857	)
Increase due to revenue recognized during the period but contingent on future performance		3,324
Decrease due to transfer to receivables during the period		(5,646	)
Adjustments		(699	)
Net balance at September 30, 2020	$	(54,652	)
Contract assets at September 30, 2020	$	3,266
Contract liabilities at September 30, 2020		(57,918	)

	September 30, 2019
	Fair Value Measurements Using
	Level 1		Level 2		Level 3		Assets at Fair Value
Money market funds	$	196,388	$	—	$	—	$	196,388

	Nine Months Ended September 30, 2019
Operating cash flows used for operating leases	$	30,235
Right-of-use assets obtained in exchange for lease liabilities		16,564
Weighted-average remaining lease term	6.8 years
Weighted-average discount rate		8.64	%

2019	$	28,373
2020		27,144
2021		26,565
2022		26,281
2023		26,280
Thereafter		64,062
Total lease payments	$	198,705

2019 (excluding nine months ended September 30, 2019)	$	8,372
2020		30,627
2021		28,696
2022		28,252
2023		28,236
2024		28,315
Thereafter		46,448
Total lease payments		198,946
Less: interest		(49,582	)
Total lease liability	$	149,364
Amounts recognized in unaudited Condensed Consolidated Balance Sheets:
Accrued liabilities	$	19,143
Other liabilities		130,221
Total operating lease liability	$	149,364


Exhibit No.		Description of Exhibit

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

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

32.1*		Section 1350 Certification of the Chief Executive Officer and Chief Financial ~~Officer.~~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 September 30, ~~2019,~~2020, formatted in Inline XBRL (included with the Exhibit 101 attachments).


	DIAMOND OFFSHORE DRILLING, INC.
	(Registrant)

Date ~~October 28, 2019~~November 2, 2020	By:	/s/ Scott Kornblau
		Scott Kornblau
		Senior Vice President and Chief Financial Officer


Date ~~October 28, 2019~~November 2, 2020		/s/ ~~Beth G. Gordon~~Dominic A. Savarino
		~~Beth G. Gordon~~Dominic A. Savarino
		Vice President and ~~Controller (Chief~~Chief Accounting ~~Officer)~~& Tax Officer