Edgar Filing: Ocean Rig UDW Inc.

d1367785_20-f.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 20-F

o REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR 12(g) OF THE SECURITIES EXCHANGE ACT OF 1934

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

For the fiscal year ended December 31, 2012

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

For the transition period from to

o SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Date of event requiring this shell company report: Not applicable

Commission file number 001-35298

OCEAN RIG UDW INC.

(Exact name of Registrant as specified in its charter)

(Translation of Registrant's name into English)

Republic of the Marshall Islands

(Jurisdiction of incorporation or organization)

10 Skopa Street, Tribune House

2nd Floor, Office 202, CY 1075

Nicosia, Cyprus

(Address of principal executive offices)

Mr. Savvas D. Georghiades,

Telephone: +357 22767517, Fax: +357 22761542

10 Skopa Street, Tribune House

2nd Floor, Office 202, CY 1075

Nicosia, Cyprus

(Name, Telephone, E-mail and/or Facsimile number and Address of Company Contact Person)

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


Title of class		Name of exchange on which registered

Common stock, $0.01 par value		The NASDAQ Stock Market LLC
Preferred stock purchase rights		The NASDAQ Stock Market LLC

Securities registered or to be registered pursuant to Section 12(g) of the Act: None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act: None

Indicate the number of outstanding shares of each of the issuer's classes of capital or common stock as of the close of the period covered by the annual report: As of December 31, 2012, there were 131,725,128 shares of the registrant's common stock, $0.01 par value, outstanding.

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. x Yes ¨ No

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934. ¨ Yes x No

Note—Checking the box above will not relieve any registrant required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 from their obligations under those Sections.

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. x Yes ¨ No

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See the definitions of accelerated filer and large accelerated filer in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ¨ Accelerated filer x Non-accelerated filer ¨

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:


	US GAAP x	International Financial Reporting Standards as issued by the International Accounting Standards Board ¨	Other ¨

If "Other" has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow. ¨ Item 17 ¨Item 18

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ¨ Yes x No

TABLE OF CONTENTS

FORWARD-LOOKING STATEMENTS		1
PART I		3
Item 1.	Identity of Directors, Senior Management and Advisers	3
Item 2.	Offer Statistics and Expected Timetable	3
Item 3.	Key Information	3
Item 4.	Information on the Company	30
Item 4A.	Unresolved Staff Comments	41
Item 5.	Operating and Financial Review and Prospects	41
Item 6.	Directors, Senior Management and Employees	65
Item 7.	Major Shareholders and Related Party Transactions	71
Item 8.	Financial Information	75
Item 9.	The Offer and Listing	76
Item 10.	Additional Information	78
Item 11.	Quantitative and Qualitative Disclosures about Market Risk	82
Item 12.	Description of Securities Other than Equity Securities	84
PART II		85
Item 13.	Defaults, Dividend Arrearages and Delinquencies	85
Item 14.	Material Modifications to the Rights of Security Holders and Use of Proceeds	85
Item 15.	Controls and Procedures	85
Item 16A.	Audit Committee Financial Expert	86
Item 16B.	Code of Ethics	86
Item 16C.	Principal Accountant Fees and Services	86
Item 16D	Exemptions from the Listing Standards for Audit Committees	87
Item 16E.	Purchases of Equity Securities by the Issuer and Affiliated Purchasers	87
Item 16F	Change in Registrant's Certifying Accountant	87
Item 16G.	Corporate Governance	87
Item 16H.	Mine Safety Disclosure	87
PART III		88
Item 17.	Financial Statements	88
Item 18.	Financial Statements	88
Item 19.	Exhibits	88

FORWARD-LOOKING STATEMENTS

The Private Securities Litigation Reform Act of 1995 provides safe harbor protections for forward-looking statements in order to encourage companies to provide prospective information about their business. The Company desires to take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 and is including this cautionary statement in connection with such safe harbor legislation.

This annual report and any other written or oral statements made by us or on our behalf may include forward-looking statements which reflect our current views and assumptions with respect to future events and financial performance and are subject to risks and uncertainties. Forward-looking statements include statements concerning plans, objectives, goals, strategies, future events or performance, and underlying assumptions and other statements, which are other than statements of historical or present facts or conditions. The words "believe," "anticipate," "intend," "estimate," "forecast," "project," "plan," "potential," "may," "should," "expect" and similar expressions identify forward-looking statements.

The forward-looking statements in this document are based upon various assumptions, many of which are based, in turn, upon further assumptions, including without limitation, management's examination of historical operating trends, data contained in our records and other data available from third parties. Although we believe that these assumptions were reasonable when made, because these assumptions are inherently subject to significant uncertainties and contingencies which are difficult or impossible to predict and are beyond our control, we cannot assure you that we will achieve or accomplish the expectations, beliefs or projections described in the forward-looking statements contained in this annual report.

In addition to these important factors and matters discussed elsewhere in this annual report, important factors that, in our view, could cause actual results to differ materially from those discussed in the forward-looking statements include factors related to:

the offshore drilling market, including supply and demand, utilization rates, dayrates, customer drilling programs, commodity prices, effects of new rigs and drillships on the market and effects of declines in commodity prices and downturn in global economy on market outlook for our various geographical operating sectors and classes of rigs and drillships;

hazards inherent in the offshore drilling industry and marine operations causing personal injury or loss of life, severe damage to or destruction of property and equipment, pollution or environmental damage, claims by third parties or customers and suspension of operations;

customer contracts, including contract backlog, contract commencements, contract terminations, contract option exercises, contract revenues, contract awards and rig and drillship mobilizations, performance provisions, newbuildings, upgrades, shipyard and other capital projects, including completion, delivery and commencement of operations dates, expected downtime and lost revenue;

political and other uncertainties, including political unrest, risks of terrorist acts, war and civil disturbances, piracy, significant governmental influence over many aspects of local economies, seizure, nationalization or expropriation of property or equipment;

repudiation, nullification, termination, modification or renegotiation of contracts;

limitations on insurance coverage, such as war risk coverage, in certain areas;

foreign and U.S. monetary policy and foreign currency fluctuations and devaluations;

the inability to repatriate income or capital;

complications associated with repairing and replacing equipment in remote locations;

import-export quotas, wage and price controls imposition of trade barriers;

regulatory or financial requirements to comply with foreign bureaucratic actions, including potential limitations on drilling activity;

changing taxation policies and other forms of government regulation and economic conditions that are beyond our control;

the level of expected capital expenditures and the timing and cost of completion of capital projects;

our ability to successfully employ both our existing and newbuilding drilling units, procure or have access to financing, ability to comply with loan covenants, liquidity and adequacy of cash flow for our obligations;

continued borrowing availability under our debt agreements and compliance with the covenants contained therein;

our substantial leverage, including our ability to generate sufficient cash flow to service our existing debt and the incurrence of substantial indebtedness in the future;

factors affecting our results of operations and cash flow from operations, including revenues and expenses, uses of excess cash, including debt retirement, dividends, timing and proceeds of asset sales, tax matters, changes in tax laws, treaties and regulations, tax assessments and liabilities for tax issues, legal and regulatory matters, including results and effects of legal proceedings, customs and environmental matters, insurance matters, debt levels, including impacts of the financial and credit crisis;

the effects of accounting changes and adoption of accounting policies;

recruitment and retention of personnel; and

other important factors described in "Item 3. Key Information—D. Risk factors."

We caution readers of this annual report not to place undue reliance on these forward-looking statements.

All forward-looking statements made in this annual report are qualified by these cautionary statements. These forward-looking statements are made only as of the date of this annual report, and we expressly disclaim any obligation to update or revise any forward-looking statements to reflect changes in assumptions, the occurrence of unanticipated events, changes in future operating results over time or otherwise.

Please note in this annual report, "we," "us," "our," "Ocean Rig UDW" and "the Company," all refer to Ocean Rig UDW Inc. and its subsidiaries, unless the context otherwise requires.

PART I

Item 1. Identity of Directors, Senior Management and Advisers

Not applicable.

Item 2. Offer Statistics and Expected Timetable

Not applicable.

Item 3. Key Information

A. Selected Historical Consolidated Financial Data

The following table sets forth our selected historical consolidated financial and other data, at the dates and for the periods indicated. We were incorporated on December 10, 2007 under the name Primelead Shareholders Inc.. Primelead Shareholders Inc. was formed for the purposes of acquiring the shares of our predecessor, Ocean Rig ASA, which was incorporated in September 1996 under the laws of Norway. We acquired control of Ocean Rig ASA on May 14, 2008. The selected historical consolidated financial data as of December 31, 2012 and 2011 and for the years ended December 31, 2012, 2011 and 2010 is derived from the audited financial statements and related notes of Ocean Rig UDW Inc. and its subsidiaries ("successor") appearing elsewhere in this annual report.

The selected historical consolidated financial data as of December 31, 2009 and 2008 and for the year ended December 31, 2008 are derived from the successor audited financial statements and related notes not included in this annual report. The selected historical consolidated financial and other data of Ocean Rig ASA and its subsidiaries ("predecessor") as of and for the period from January 1 to May 14, 2008 is derived from the audited financial statements of Ocean Rig ASA not included in this annual report.

We refer you to the notes to the consolidated financial statements for a discussion of the basis on which the consolidated financial statements are presented. The selected historical consolidated financial and other data should be read in conjunction with "Item 5. Operating and Financial Review and Prospects" and the audited consolidated financial statements, the related notes thereto and other financial information appearing elsewhere in this annual report.

	Ocean Rig ASA (predecessor)			Ocean Rig UDW Inc. (successor)
(U.S. Dollars in	As of May 14,			Year Ended December 31,
thousands)	2008			2008			2009			2010			2011			2012
Income statement data:	2008			2008			2009			2010			2011			2012
Income statement data:
Total revenues		99,172			218,663			388,122			405,712			699,649			941,903
Drilling rigs and drillships operating expenses		48,144			86,229			133,256			119,369			281,833			563,583
Goodwill impairment		-			761,729			-			-			-			-
Loss on disposals		-			-			-			1,458			754			133
Depreciation and amortization		19,367			45,432			75,348			75,092			162,532			224,479
Legal settlements and other, net		-			-			-			-			-			4,524
General and administrative expenses		12,140			15,052			20,423			20,566			46,718			83,647
Total operating expenses		79,651			908,442			229,027			216,485			491,837			876,366

Operating income/(loss)		19,521			(689,779	)		159,095			189,227			207,812			65,537
Interest and finance costs		(41,661	)		(71,692	)		(46,120	)		(8,418	)		(63,752	)		(116,427	)
Interest income		381			3,033			6,259			12,464			9,810			553
Gain/(loss) on interest rate swaps		-			-			4,826			(40,303	)		(33,455	)		(36,974	)
Other income/(expense)		-			(1,710	)		4,491			2,227			2,311			(1,068	)
Total finance expenses, net		(41,280	)		(70,369	)		(30,544	)		(34,030	)		(85,086	)		(153,916	)

Income/(loss) before income taxes		(21,759	)		(760,148	)		128,551			155,197			122,726			(88,379	)
Income/(loss) taxes		(1,637	)		(2,844	)		(12,797	)		(20,436	)		(27,428	)		(43,957	)
Equity in income/(loss) of investee		-			(1,055	)		-			-			-			-
Net income/(loss)		(23,396	)		(764,047	)		115,754			134,761			95,298			(132,336	)
Less: Net income attributable to non controlling interest		-			(1,800	)		-			-			-			-
Net income/(loss)		(23,396	)	$	(765,847	)	$	115,754		$	134,761		$	95,298		$	(132,336	)
Earnings/ (loss) per common share, basic and diluted		(0.14	)	$	(7.43	)	$	1.12		$	1.30		$	0.72		$	(1.00	)
Weighted average number of common shares, basic and diluted		162,171,380			103,125,000			103,125,000			103,908,279			131,696,928			131,696,935

	Ocean Rig ASA (predecessor)		Ocean Rig UDW Inc. (successor)
(U.S. Dollars in	As of May 14,		As of December 31,
thousands)	2008		2008		2009		2010		2011		2012
Balance sheet data:
Cash and cash equivalents		-		272,940		234,195		95,707		250,878		317,366
Other current assets		96,471		93,379		324,363		576,299		245,531		279,768
Total current assets		96,471		366,319		558,558		672,006		496,409		597,134
Drilling rigs, drillships, machinery and equipment, net		1,132,867		1,377,359		1,317,607		1,249,333		4,538,838		4,399,462
Intangible assets, net		-		13,391		11,948		10,506		9,062		7,619
Other non current assets		-		3,612		43,480		523,363		216,121		228,074
Advances for rigs and drillships under construction		-		-		1,178,392		1,888,490		754,925		992,825
Total assets		1,229,338		1,760,681		3,109,985		4,343,698		6,015,355		6,225,114
Current liabilities, including current portion of long term debt		538,679		885,039		682,287		667,918		427,557		505,665
Total long term debt, excluding current portion		281,307		788,314		662,362		696,986		2,525,599		2,683,630
Other non current liabilities		2,470		63,697		64,219		97,712		63,743		127,304
Total liabilities		822,456		1,737,050		1,408,868		1,462,616		3,016,899		3,316,599
Stockholders' equity		406,882		23,631		1,701,117		2,881,082		2,998,456		2,908,515
Total liabilities and stockholders' equity	$	1,229,338	$	1,760,681	$	3,109,985	$	4,343,698		6,015,355	$	6,225,114

	Ocean Rig ASA (predecessor)			Ocean Rig UDW Inc. (successor)
(U.S. Dollars in	January 1,			Year Ended December 31,
thousands, except	2008 to May			Year Ended December 31,
for operating data)		14, 2008			2008			2009			2010			2011			2012
Cash flow data:
Net cash provided by / (used in):
Operating activities	$	(29,089	)	$	21,119		$	211,075		$	221,798		$	270,662		$	278,303
Investing activities		(10,463	)		(1,020,673	)		(146,779	)		(1,441,347	)		(1,561,501	)		(320,469	)
Financing activities		8,550			1,257,390			(103,041	)		1,081,061			1,446,010			108,654
Other financial data
EBITDA (1)		38,888			(648,912	)		243,760			226,243			339,200			251,974
Cash paid for interest		22,628			23,103			51,093			43,203			32,164			73,219
Capital expenditures		(10,463	)		(16,584	)		(14,152	)		(6,834	)		(78,480	)		(97,869	)
Payments for drillships under construction		-			-			(130,832	)		(705,022	)		(1,864,862	)		(212,185	)
Operating data, when on hire
Operating units		2			2			2			2			6			6

______________________

(1) EBITDA represents net income before interest, taxes, depreciation and amortization. EBITDA is a non-U.S. generally accepted accounting principles, or U.S. GAAP, measure and does not represent and should not be considered as an alternative to net income or cash flow from operations, as determined by GAAP or other GAAP measures, and our calculation of EBITDA may not be comparable to that reported by other companies. EBITDA is included herein because it is a basis upon which we measure our operations and efficiency.

	Ocean Rig ASA (predecessor)			Ocean Rig UDW Inc. (successor)
	January 1,
(U.S. Dollars in	2008 to May			Year Ended December 31,
thousands)		14, 2008			2008			2009		2010			2011	2012
EBITDA reconciliation
Net income / (loss)		(23,396	)	$	(765,847	)	$	115,754	$	134,761		$	95,298	(132,336	)
Add: Depreciation and amortization		19,367			45,432			75,348		75,092			162,532	224,479
Add: Net interest expense / income		41,280			68,659			39,861		(4,046	)		53,942	115,874
Add: Income taxes		1,637			2,844			12,797		20,436			27,428	43,957
EBITDA		38,888		$	(648,912	)	$	243,760	$	226,243		$	339,200	251,974

B. Capitalization and Indebtedness

Not applicable.

C. Reasons for the Offer and Use of Proceeds

Not applicable.

D. Risk Factors

Some of the following risks relate principally to the industry in which we operate and our business in general. Other risks relate principally to the securities market and ownership of our common stock. The occurrence of any of the events described in this section could significantly and negatively affect our business, financial condition, operating results, cash flows or our ability to pay dividends, if any, in the future, or the trading price of our common stock.

Risks Relating to Our Industry

Our business depends on the level of activity in the offshore oil and gas industry, which is significantly affected by, among other things, volatile oil and gas prices and may be materially and adversely affected by a decline in the offshore oil and gas industry.

The offshore contract drilling industry is cyclical and volatile. Our business depends on the level of activity in oil and gas exploration, development and production in offshore areas worldwide. The availability of quality drilling prospects, exploration success, relative production costs, the stage of reservoir development and political and regulatory environments affect customers' drilling programs. Oil and gas prices and market expectations of potential changes in these prices also significantly affect this level of activity and demand for drilling units.

Oil and gas prices are extremely volatile and are affected by numerous factors beyond our control, including the following:

worldwide production and demand for oil and gas and any geographical dislocations in supply and demand;

the cost of exploring for, developing, producing and delivering oil and gas;

expectations regarding future energy prices;

advances in exploration, development and production technology;

the ability of the Organization of Petroleum Exporting Countries, or OPEC, to set and maintain levels and pricing;

the level of production in non-OPEC countries;

government regulations;

local and international political, economic and weather conditions;

domestic and foreign tax policies;

development and exploitation of alternative fuels;

the policies of various governments regarding exploration and development of their oil and gas reserves; and

the worldwide military and political environment, including uncertainty or instability resulting from an escalation or additional outbreak of armed hostilities, insurrection or other crises in the Middle East or other geographic areas or further acts of terrorism in the United States, or elsewhere.

Declines in oil and gas prices for an extended period of time, or market expectations of potential decreases in these prices, could negatively affect our business in the offshore drilling sector. Crude oil inventories remain at high levels compared to historical levels, which may place downward pressure on the price of crude oil and demand for offshore drilling units. Sustained periods of low oil prices typically result in reduced exploration and drilling because oil and gas companies' capital expenditure budgets are subject to cash flow from such activities and are therefore sensitive to changes in energy prices. These changes in commodity prices can have a dramatic effect on rig demand, and periods of low demand can cause excess rig supply and intensify the competition in the industry which often results in drilling units, particularly lower specification drilling units, being idle for long periods of time. We cannot predict the future level of demand for our services or future conditions of the oil and gas industry. Any decrease in exploration, development or production expenditures by oil and gas companies could reduce our revenues and materially harm our business and results of operations.

In addition to oil and gas prices, the offshore drilling industry is influenced by additional factors, including:

the availability of competing offshore drilling vessels and the level of newbuilding activity for drilling vessels;

the level of costs for associated offshore oilfield and construction services;

oil and gas transportation costs;

the discovery of new oil and gas reserves;

the cost of non-conventional hydrocarbons, such as the exploitation of oil sands; and

regulatory restrictions on offshore drilling.

Any of these factors could reduce demand for our services and adversely affect our business and results of operations.

Continuation of the recent worldwide economic downturn could have a material adverse effect on our revenue, profitability and financial position.

Although there are signs that the economic recession has abated in many countries, there is still considerable instability in the world economy, due in part to uncertainty related to continuing discussions in the United States regarding the federal debt ceiling and in the economies of Eurozone countries, such as Greece, Spain, Portugal, Ireland and Italy, where a new economic downturn has introduced further volatility in the global markets. Further decrease in global economic activity would likely reduce worldwide demand for energy and result in an extended period of lower crude oil and natural gas prices. In addition, continued hostilities and insurrections in the Middle East and North Africa and the occurrence or threat of terrorist attacks against the United States or other countries could adversely affect the economies of the United States and of other countries. Any prolonged reduction in crude oil and natural gas prices would depress the levels of exploration, development and production activity. Moreover, even during periods of high commodity prices, customers may cancel or curtail their drilling programs, or reduce their levels of capital expenditures for exploration and production for a variety of reasons, including their lack of success in exploration efforts. These factors could cause our revenues and margins to decline, decrease daily rates and utilization of our drilling units and limit our future growth prospects. Any significant decrease in daily rates or utilization of our drilling units could materially reduce our revenues and profitability. In addition, any instability in the financial and insurance markets, as experienced in the recent financial and credit crisis, could make it more difficult for us to access capital and to obtain insurance coverage that we consider adequate or is otherwise required by our drilling contracts.

The current state of global financial markets and current economic conditions may adversely impact our ability to obtain additional financing on acceptable terms, which may hinder or prevent us from expanding our business.

Global financial markets and economic conditions have been, and continue to be, volatile. Recently, the debt and equity capital markets have been severely distressed. These issues, along with significant write-offs in the financial services sector, the re-pricing of credit risk and the current weak economic conditions, have made, and will likely continue to make, it difficult to obtain additional financing. The current state of global financial markets and current economic conditions might adversely impact our ability to issue additional equity at prices which will not be dilutive to our existing shareholders or preclude us from issuing equity at all.

Also, as a result of concerns about the stability of financial markets generally and the solvency of counterparties specifically, the cost of obtaining money from the credit markets has increased as many lenders have increased interest rates, enacted tighter lending standards, refused to refinance existing debt at all or on terms similar to current debt and reduced, and in some cases ceased, to provide funding to borrowers. Due to these factors, we cannot be certain that additional financing will be available if needed and to the extent required, on acceptable terms or at all. If additional financing is not available when needed, or is available only on unfavorable terms, we may be unable to meet our obligations as they come due or we may be unable to enhance our existing business, complete additional drilling unit acquisitions or otherwise take advantage of business opportunities as they arise.

The offshore drilling industry is highly competitive with intense price competition and, as a result, we may be unable to compete successfully with other providers of contract drilling services that have greater resources than we have.

The offshore contract drilling industry is highly competitive with several industry participants, none of which has a dominant market share, and is characterized by high capital and maintenance requirements. Drilling contracts are traditionally awarded on a competitive bid basis. Price competition is often the primary factor in determining which qualified contractor is awarded the drilling contract, although drilling unit availability, location and suitability, the quality and technical capability of service and equipment, reputation and industry standing are key factors which are considered. Mergers among oil and natural gas exploration and production companies have reduced, and may from time to time further reduce, the number of available customers, which would increase the ability of potential customers to achieve pricing terms favorable to them.

Many of our competitors are significantly larger than we are and have more diverse drilling assets and significantly greater financial and other resources than we have. In addition, because of our relatively small fleet, we may be unable to take advantage of economies of scale to the same extent as some of our larger competitors. Given the high capital requirements that are inherent in the offshore drilling industry, we may also be unable to invest in new technologies or expand in the future as may be necessary for us to succeed in this industry, while our larger competitors with superior financial resources, and in many cases less leverage than we have, may be able to respond more rapidly to changing market demands and compete more efficiently on price for drillship and drilling rig employment. We may not be able to maintain our competitive position, and we believe that competition for contracts will continue to be intense in the future. Our inability to compete successfully may reduce our revenues and profitability.

An over-supply of drilling units may lead to a reduction in dayrates and therefore may materially impact our profitability.

During the recent period of high utilization and high dayrates, industry participants have increased the supply of drilling units by ordering the construction of new drilling units. Historically, this has resulted in an over-supply of drilling units and has caused a subsequent decline in utilization and dayrates when the drilling units enter the market, sometimes for extended periods of time until the units have been absorbed into the active fleet. According to industry sources, the worldwide fleet of ultra-deepwater drilling units as of February 2013 consisted of 121 units, comprised of 59 semi-submersible rigs and 62 drillships. An additional 14 semi-submersible rigs and 71 drillships were under construction or on order as of February 2013, which would bring the total fleet to 206 drilling units by the end of 2020. A relatively large number of the drilling units currently under construction have been contracted for future work, which may intensify price competition as scheduled delivery dates occur. The entry into service of these new, upgraded or reactivated drilling units will increase supply and has already led to a reduction in dayrates as drilling units are absorbed into the active fleet. In addition, the new construction of high-specification drilling units, as well as changes in our competitors' drilling unit fleets, could require us to make material additional capital investments to keep our fleet competitive. Lower utilization and dayrates could adversely affect our revenues and profitability. Prolonged periods of low utilization and dayrates could also result in the recognition of impairment charges on our drilling units if future cash flow estimates, based upon information available to management at the time, indicate that the carrying value of these drilling units may not be recoverable.

Consolidation of suppliers may increase the cost of obtaining supplies, which may have a material adverse effect on our results of operations and financial condition.

We rely on certain third parties to provide supplies and services necessary for our operations, including, but not limited to, drilling equipment suppliers and catering and machinery suppliers. Recent mergers have reduced the number of available suppliers, resulting in fewer alternatives for sourcing key supplies. Such consolidation, combined with a high volume of drilling units under construction, may result in a shortage of supplies and services, thereby increasing the cost of supplies and/or potentially inhibiting the ability of suppliers to deliver on time, or at all. These cost increases, delays or unavailability could have a material adverse effect on our results of operations and result in drilling unit downtime and delays in the repair and maintenance of our drilling units.

Our international operations involve additional risks, which could adversely affect our business.

We operate in various regions throughout the world. Our drilling rig, the Leiv Eiriksson, is currently undergoing equipment and winterization upgrades and is expected to commence drilling operations on the Norwegian Continental Shelf on or prior to April 15, 2013, our drilling rig, the Eirik Raude, is mobilizing from offshore West Africa to offshore Ireland, where it is expected to commence drilling operations, our drillships, the Ocean Rig Corcovado and the Ocean Rig Mykonos, are operating offshore Brazil and our drillships, the Ocean Rig Olympia and the Ocean Rig Poseidon, are operating offshore Ivory Coast and Tanzania, respectively.

In the past, the Eirik Raude has operated in the Gulf of Mexico and offshore Canada, Norway, the United Kingdom, Ghana and the Ivory Coast, while the Leiv Eiriksson has operated offshore Greenland, West Africa, Turkey, Ireland, west of the Shetland Islands, the Falkland Islands and in the North Sea, and the Ocean Rig Corcovado and the Ocean Rig Olympia have operated offshore Greenland and West Africa, respectively. As a result of our international operations, we may be exposed to political and other uncertainties, including risks of:

terrorist and environmental activist acts, armed hostilities, war and civil disturbances;

acts of piracy, which have historically affected ocean-going vessels trading in regions of the world such as the South China Sea and in the Gulf of Aden off the coast of Somalia and which have generally increased significantly in frequency since 2008, particularly in the Gulf of Aden and off the west coast of Africa;

significant governmental influence over many aspects of local economies;

seizure, nationalization or expropriation of property or equipment;

repudiation, nullification, modification or renegotiation of contracts;

limitations on insurance coverage, such as war risk coverage, in certain areas;

political unrest;

foreign and U.S. monetary policy, government debt downgrades and potential defaults and foreign currency fluctuations and devaluations;

the inability to repatriate income or capital;

complications associated with repairing and replacing equipment in remote locations;

import-export quotas, wage and price controls, imposition of trade barriers;

regulatory or financial requirements to comply with foreign bureaucratic actions;

changing taxation policies, including confiscatory taxation;

other forms of government regulation and economic conditions that are beyond our control; and

governmental corruption.

In addition, international contract drilling operations are subject to various laws and regulations in countries in which we operate, including laws and regulations relating to:

the equipping and operation of drilling units;

repatriation of foreign earnings;

oil and gas exploration and development;

taxation of offshore earnings and earnings of expatriate personnel; and

use and compensation of local employees and suppliers by foreign contractors.

Some foreign governments favor or effectively require (i) the awarding of drilling contracts to local contractors or to drilling rigs owned by their own citizens, (ii) the use of a local agent or (iii) foreign contractors to employ citizens of, or purchase supplies from, a particular jurisdiction. These practices may adversely affect our ability to compete in those regions. It is difficult to predict what governmental regulations may be enacted in the future that could adversely affect the international drilling industry. The actions of foreign governments, including initiatives by OPEC, may adversely affect our ability to compete. Failure to comply with applicable laws and regulations, including those relating to sanctions and export restrictions, may subject us to criminal sanctions or civil remedies, including fines, denial of export privileges, injunctions or seizures of assets.

Our business and operations involve numerous operating hazards.

Our operations are subject to hazards inherent in the drilling industry, such as blowouts, reservoir damage, loss of production, loss of well control, lost or stuck drill strings, equipment defects, punch throughs, craterings, fires, explosions and pollution, including spills similar to the events on April 20, 2010 related to the Deepwater Horizon, in which we were not involved. Contract drilling and well servicing require the use of heavy equipment and exposure to hazardous conditions, which may subject us to liability claims by employees, customers and third parties. These hazards can cause personal injury or loss of life, severe damage to or destruction of property and equipment, pollution or environmental damage, claims by third parties or customers and suspension of operations. Our offshore fleet is also subject to hazards inherent in marine operations, either while on-site or during mobilization, such as capsizing, sinking, grounding, collision, damage from severe weather and marine life infestations. Operations may also be suspended because of machinery breakdowns, abnormal drilling conditions, personnel shortages or failure of subcontractors to perform or supply goods or services.

Damage to the environment could also result from our operations, particularly through spillage of fuel, lubricants or other chemicals and substances used in drilling operations, leaks and blowouts or extensive uncontrolled fires. We may also be subject to property, environmental and other damage claims by oil and gas companies. Our insurance policies and contractual indemnity rights with our customers may not adequately cover losses, and we do not have insurance coverage or rights to indemnity for all the risks to which we are exposed. Consistent with standard industry practice, our customers generally assume, and indemnify us against, well control and subsurface risks under dayrate drilling contracts, including pollution damage in connection with reservoir fluids stemming from operations under the contract, damage to the well or reservoir, loss of subsurface oil and gas and the cost of bringing the well under control. We generally indemnify our customers against pollution from substances in our control that originate from the drilling unit (e.g., diesel used onboard the unit or other fluids stored onboard the unit and above the water surface). However, our drilling contracts are individually negotiated, and the degree of indemnification we receive from the customer against the liabilities discussed above can vary from contract to contract, based on market conditions and customer requirements existing when the contract was negotiated. Notwithstanding a contractual indemnity from a customer, there can be no assurance that our customers will be financially able to indemnify us or will otherwise honor their contractual indemnity obligations. We maintain insurance coverage for property damage, occupational injury and illness, and general and marine third-party liabilities. However, pollution and environmental risks generally are not totally insurable. Furthermore, we have no insurance coverage for named storms in the Gulf of Mexico and while trading within war risks excluded areas.

The Deepwater Horizon oil spill in the Gulf of Mexico may result in more stringent laws and regulations governing deepwater drilling, which could have a material adverse effect on our business, operating results or financial condition.

On April 20, 2010, there was an explosion and a related fire on the Deepwater Horizon, an ultra-deepwater semi-submersible drilling unit that is not connected to us, while it was servicing the Macondo well in the Gulf of Mexico. This catastrophic event resulted in the death of 11 workers and the total loss of that drilling unit, as well as the release of large amounts of oil into the Gulf of Mexico, severely impacting the environment and the region's key industries. This event is being investigated by several federal agencies, including the U.S. Department of Justice, and by the U.S. Congress, and is also the subject of numerous lawsuits. On January 11, 2011, the National Commission on the BP Deepwater Horizon Oil Spill and Offshore Drilling released its final report, with recommendations for new regulations.

We do not currently operate our drilling units in these regions, but we may do so in the future. In any event, changes to leasing and drilling activity requirements as a result of the Deepwater Horizon incident could have a substantial impact on the offshore oil and gas industry worldwide. All drilling activity in the U.S. Gulf of Mexico must be in compliance with enhanced safety requirements contained in Notices to Lessees 2010-N05 and 2010 N-06. Effective October 22, 2012 all drilling in the U.S. Gulf of Mexico must also comply with the Final Drilling Safety Rule as adopted on August 15, 2012, which enhances safety measures for energy development on the outer continental shelf. All drilling must also comply with the Workplace Safety Rule on Safety and Environmental Management Systems. We continue to evaluate these requirements to ensure that our rigs and equipment are in full compliance, where applicable. Additional requirements could be forthcoming based on further recommendations by regulatory agencies investigating the Macondo well incident.

We are not able to predict the extent of future leasing plans or the likelihood, nature or extent of additional rulemaking. Nor are we able to predict when the Bureau of Ocean Energy Management (BOEM) will enter into leases with our customers or when the Bureau of Safety and Environmental Enforcement (BSEE) will issue drilling permits to our customers. We are not able to predict the future impact of these events on our operations. The current and future regulatory environment in the Gulf of Mexico could impact the demand for drilling units in the Gulf of Mexico in terms of overall number of rigs in operations and the technical specification required for offshore rigs to operate in the Gulf of Mexico. It is possible that short-term potential migration of rigs from the Gulf of Mexico could adversely impact dayrates levels and fleet utilization in other regions. In addition, insurance costs across the industry have increased as a result of the Macondo well incident and certain insurance coverage has become more costly, less available, and not available at all from certain insurance companies.

Our insurance coverage may not adequately protect us from certain operational risks inherent in the drilling industry.

Our insurance is intended to cover normal risks in our current operations, including insurance against property damage, occupational injury and illness, loss of hire, certain war risks and third-party liability, including pollution liability. For example, the amount of risk we are subject to might increase regarding occupational injuries because on January 12, 2012, the U.S. Supreme Court ruled that the U.S. Outer Continental Shelf Lands Act could cover occupational injuries.

Insurance coverage may not, under certain circumstances, be available, and if available, may not provide sufficient funds to protect us from all losses and liabilities that could result from our operations. We have also obtained loss of hire insurance which becomes effective after 45 days of downtime with coverage that extends for approximately one year. This loss of hire insurance is recoverable only if there is physical damage to the rig or equipment which is caused by a peril against which we are insured. The principal risks which may not be insurable are various environmental liabilities and liabilities resulting from reservoir damage caused by our gross negligence. Moreover, our insurance provides for premium adjustments based on claims and is subject to deductibles and aggregate recovery limits. In the case of pollution liabilities, our deductible is $10,000 per event and $250,000 for protection and indemnity claims brought before any U.S. jurisdiction. The deductible for collision liability claims is $50,000. Our aggregate recovery limit is $500.0 million for all claims arising out of any event covered by our protection and indemnity insurance. Our deductible is $1.5 million per hull and machinery insurance claim. In addition, insurance policies covering physical damage claims due to a named windstorm in the Gulf of Mexico generally impose strict recovery limits. Our insurance coverage may not protect fully against losses resulting from a required cessation of drilling unit operations for environmental or other reasons. Insurance may not be available to us at all or on terms acceptable to us, we may not maintain insurance or, if we are so insured, our policy may not be adequate to cover our loss or liability in all cases. The occurrence of a casualty, loss or liability against, which we may not be fully insured against, could significantly reduce our revenues, make it financially impossible for us to obtain a replacement drilling unit or to repair a damaged drilling unit, cause us to pay fines or damages which are generally not insurable and that may have priority over the payment obligations under our indebtedness or otherwise impair our ability to meet our obligations under our indebtedness and to operate profitably.

If we enter into drilling contracts or engage in certain other activities with countries or government-controlled entities or customers associated with countries that are subject to restrictions imposed by the U.S. government, or engage in certain other activities, including entering into drilling contracts with individuals or entities in such countries that are not controlled by their governments or engaging in operations associated with such countries or entities pursuant to contracts with third parties unrelated to those countries or entities, our ability to conduct our business and access U.S. capital markets and our reputation and the market for our securities could be adversely affected.

Although none of our drilling units have operated in countries subject to sanctions and embargoes imposed by the U.S. government and other authorities or countries identified by the U.S. government or other authorities as state sponsors of terrorism, including Cuba, Iran, Sudan and Syria, in the future our drilling units may operate in these countries from time to time on our customers' instructions. The U.S. sanctions and embargo laws and regulations vary in their application, as they do not all apply to the same covered persons or proscribe the same activities, and such sanctions and embargo laws and regulations may be amended or strengthened over time. In 2010, the U.S. enacted the Comprehensive Iran Sanctions Accountability and Divestment Act, or CISADA, which amended the Iran Sanctions Act. Among other things, CISADA introduced limits on the ability of companies and persons to do business or trade with Iran when such activities relate to the investment, supply or export of refined petroleum or petroleum products. In 2012, President Obama signed Executive Order 13608 which prohibits foreign persons from violating or attempting to violate, or causing a violation of any sanctions in effect against Iran or facilitating any deceptive transactions for or on behalf of any person subject to U.S. sanctions. Any persons found to be in violation of Executive Order 13608 will be deemed a foreign sanctions evader and will be banned from all contacts with the United States, including conducting business in U.S. dollars. Also in 2012, President Obama signed into law the Iran Threat Reduction and Syria Human Rights Act of 2012, or the Iran Threat Reduction Act, which created new sanctions and strengthened existing sanctions. Among other things, the Iran Threat Reduction Act intensifies existing sanctions regarding the provision of goods, services, infrastructure or technology to Iran's petroleum or petrochemical sector. The Iran Threat Reduction Act also includes a provision requiring the President of the United States to impose five or more sanctions from Section 6(a) of the Iran Sanctions Act, as amended, on a person the President determines is a controlling beneficial owner of, or otherwise owns, operates, or controls or insures a vessel that was used to transport crude oil from Iran to another country and (1) if the person is a controlling beneficial owner of the vessel, the person had actual knowledge the vessel was so used or (2) if the person otherwise owns, operates, or controls, or insures the vessel, the person knew or should have known the vessel was so used. Such a person could be subject to a variety of sanctions, including exclusion from U.S. capital markets, exclusion from financial transactions subject to U.S. jurisdiction, and exclusion of that person's vessels from U.S. ports for up to two years.

Although we believe that we are in compliance with all applicable sanctions and embargo laws and regulations, and intend to maintain such compliance, there can be no assurance that we will be in compliance in the future, particularly as the scope of certain laws may be unclear and may be subject to changing interpretations. Any such violation could result in fines, penalties or other sanctions that could severely impact our ability to access U.S. capital markets and conduct our business, and could result in some investors deciding, or being required, to divest their interest, or not to invest, in us. In addition, certain institutional investors may have investment policies or restrictions that prevent them from holding securities of companies that have contracts with countries identified by the U.S. government as state sponsors of terrorism. The determination by these investors not to invest in, or to divest from, our common stock may adversely affect the price at which our common stock trades. Moreover, our customers may violate applicable sanctions and embargo laws and regulations as a result of actions that do not involve us or our drilling units, and those violations could in turn negatively affect our reputation. In addition, our reputation and the market for our securities may be adversely affected if we engage in certain other activities, such as entering into drilling contracts with individuals or entities in countries subject to U.S. sanctions and embargo laws that are not controlled by the governments of those countries, or engaging in operations associated with those countries pursuant to contracts with third parties that are unrelated to those countries or entities controlled by their governments. Investor perception of the value of our common stock may be adversely affected by the consequences of war, the effects of terrorism, civil unrest and governmental actions in these and surrounding countries.

The instability of the euro or the inability of Eurozone countries to refinance their debts could have a material adverse effect on our ability to fund our future capital expenditures or refinance our debt.

As a result of the credit crisis in Europe, in particular in Greece, Italy, Ireland, Portugal and Spain, the European Commission created the European Financial Stability Facility, or the EFSF, and the European Financial Stability Mechanism, or the EFSM, to provide funding to Eurozone countries in financial difficulties that seek such support. In March 2011, the European Council agreed on the need for Eurozone countries to establish a permanent stability mechanism, the European Stability Mechanism, or the ESM, which will be activated by mutual agreement, to assume the role of the EFSF and the EFSM in providing external financial assistance to Eurozone countries after June 2013.

Despite these measures, concerns persist regarding the debt burden of certain Eurozone countries and their ability to meet future financial obligations and the overall stability of the euro. An extended period of adverse development in the outlook for European countries could make it difficult for current or potential lenders in the Eurozone to provide new loan facilities we may need to fund our future capital expenditures.

Governmental laws and regulations, including environmental laws and regulations, may add to our costs or limit our drilling activity.

Our business is affected by laws and regulations relating to the energy industry and the environment in the geographic areas where we operate. The offshore drilling industry is dependent on demand for services from the oil and gas exploration and production industry, and, accordingly, we are directly affected by the adoption of laws and regulations that, for economic, environmental or other policy reasons, curtail exploration and development drilling for oil and gas. We may be required to make significant capital expenditures to comply with governmental laws and regulations. It is also possible that these laws and regulations may, in the future, add significantly to our operating costs or significantly limit drilling activity. Our ability to compete in international contract drilling markets may be limited by foreign governmental regulations that favor or require the awarding of contracts to local contractors or by regulations requiring foreign contractors to employ citizens of, or purchase supplies from, a particular jurisdiction. Governments in some countries are increasingly active in regulating and controlling the ownership of concessions, the exploration for oil and gas, and other aspects of the oil and gas industries. Offshore drilling in certain areas has been curtailed and, in certain cases, prohibited because of concerns over protection of the environment. Operations in less developed countries can be subject to legal systems that are not as mature or predictable as those in more developed countries, which can lead to greater uncertainty in legal matters and proceedings.

To the extent new laws are enacted or other governmental actions are taken that prohibit or restrict offshore drilling or impose additional environmental protection requirements that result in increased costs to the oil and gas industry, in general, or the offshore drilling industry, in particular, our business or prospects could be materially adversely affected. The operation of our drilling units will require certain governmental approvals, the number and prerequisites of which cannot be determined until we identify the jurisdictions in which we will operate on securing contracts for the drilling units. Depending on the jurisdiction, these governmental approvals may involve public hearings and conditions that result in costly undertakings on our part. We may not obtain such approvals or such approvals may not be obtained in a timely manner. If we fail to timely secure the necessary approvals or permits, our customers may have the right to terminate or seek to renegotiate their drilling contracts to our detriment. The amendment or modification of existing laws and regulations or the adoption of new laws and regulations curtailing or further regulating exploratory or development drilling and production of oil and gas could have a material adverse effect on our business, operating results or financial condition. Future earnings may be negatively affected by compliance with any such new legislation or regulations.

We are subject to complex laws and regulations, including environmental laws and regulations that can adversely affect the cost, manner or feasibility of doing business.

Our operations are subject to numerous laws and regulations in the form of international conventions and treaties, national, state and local laws and national and international regulations in force in the jurisdictions in which our vessels operate or are registered, which can significantly affect the ownership and operation of our drilling units. These requirements include, but are not limited to, the International Convention for the Prevention of Pollution from Ships, or MARPOL, the International Convention on Civil Liability for Oil Pollution Damage of 1969, generally referred to as CLC, the International Convention on Civil Liability for Bunker Oil Pollution Damage, or Bunker Convention, the International Convention for the Safety of Life at Sea of 1974, or SOLAS, the International Safety Management Code for the Safe Operation of Ships and for Pollution Prevention, or ISM Code, the International Convention for the Control and Management of Ships' Ballast Water and Sediments in February 2004, or the BWM Convention, the U.S. Oil Pollution Act of 1990, or OPA, the Comprehensive Environmental Response, Compensation and Liability Act, or CERCLA, the U.S. Clean Water Act, the U.S. Clean Air Act, the U.S. Outer Continental Shelf Lands Act, the U.S. Maritime Transportation Security Act of 2002, or the MTSA, European Union regulations, and Brazil's National Environmental Policy Law (6938/81), Environmental Crimes Law (9605/98) and Law (9966/2000) relating to pollution in Brazilian waters.

Compliance with such laws, regulations and standards, where applicable, may require installation of costly equipment or operational changes and may affect the resale value or useful lives of our vessels. Moreover, the manner in which these laws are enforced and interpreted is constantly evolving. We may also incur additional costs in order to comply with other existing and future regulatory obligations, including, but not limited to, costs relating to air emissions, including greenhouse gases, the management of ballast waters, maintenance and inspection, development and implementation of emergency procedures and insurance coverage or other financial assurance of our ability to address pollution incidents. These costs could have a material adverse effect on our business, results of operations, cash flows and financial condition. A failure to comply with applicable laws and regulations may result in administrative and civil penalties, criminal sanctions or the suspension or termination of our operations. Environmental laws often impose strict liability for remediation of spills and releases of oil and hazardous substances, which could subject us to liability without regard to whether we were negligent or at fault. Under OPA, for example, owners, operators and bareboat charterers are jointly and severally strictly liable for the discharge of oil in U.S. waters, including the 200-nautical mile exclusive economic zone around the United States. An oil spill could result in significant liability, including fines, penalties and criminal liability and remediation costs for natural resource damages under other international and U.S. federal, state and local laws, as well as third-party damages. We are required to satisfy insurance and financial responsibility requirements for potential oil (including marine fuel) spills and other pollution incidents and our insurance may not be sufficient to cover all such risks. As a result, claims against us could result in a material adverse effect on our business, results of operations, cash flows and financial condition.

Although our drilling units are separately owned by our subsidiaries, under certain circumstances a parent company and all of the ship-owning affiliates in a group under common control engaged in a joint venture could be held liable for damages or debts owed by one of the affiliates, including liabilities for oil spills under OPA or other environmental laws. Therefore, it is possible that we could be subject to liability upon a judgment against us or any one of our subsidiaries.

Our drilling units could cause the release of oil or hazardous substances, especially as our drilling units age. Any releases may be large in quantity, above our permitted limits or occur in protected or sensitive areas where public interest groups or governmental authorities have special interests. Any releases of oil or hazardous substances could result in fines and other costs to us, such as costs to upgrade our drilling rigs, clean up the releases, and comply with more stringent requirements in our discharge permits. Moreover, these releases may result in our customers or governmental authorities suspending or terminating our operations in the affected area, which could have a material adverse effect on our business, results of operation and financial condition.

If we are able to obtain from our customers some degree of contractual indemnification against pollution and environmental damages in our contracts, such indemnification may not be enforceable in all instances or the customer may not be financially able to comply with its indemnity obligations in all cases. In addition, we may not be able to obtain such indemnification agreements in the future.

Our insurance coverage may not be available in the future or we may not obtain certain insurance coverage. If it is available and we have the coverage, it may not be adequate to cover our liabilities. Any of these scenarios could have a material adverse effect on our business, operating results and financial condition.

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

Currently, emissions of greenhouse gases from ships involved in international transport are not subject to the Kyoto Protocol to the United Nations Framework Convention on Climate Change, which entered into force in 2005 and pursuant to which adopting countries have been required to implement national programs to reduce greenhouse gas emissions. As of January 1, 2013, all ships (including rigs and drillships) must comply with mandatory requirements adopted by the MEPC in July 2011 relating to greenhouse gas emissions. All ships are required to follow the Ship Energy Efficiency Management Plans. Now the minimum energy efficiency levels per capacity mile, outlined in the Energy Efficiency Design Index, applies to all new ships. These requirements could cause us to incur additional compliance costs. The IMO is also considering the implementation of market-based mechanisms to reduce greenhouse gas emissions from ships. The European Union has indicated that it intends to propose an expansion of the existing European Union emissions trading scheme to include emissions of greenhouse gases from marine vessels, and in January 2012 the European Commission launched a public consultation on possible measures to reduce greenhouse gas emissions from ships. In the United States, the EPA has issued a finding that greenhouse gases endanger public health and safety and has adopted regulations to limit greenhouse gas emissions from certain mobile sources and large stationary sources. Although the mobile source emissions regulations do not apply to greenhouse gas emissions from vessels, such regulation of vessels is foreseeable, and the EPA has in recent years received petitions from the California Attorney General and various environmental groups seeking such regulation. Any passage of climate control legislation or other regulatory initiatives by the IMO, European Union, the U.S. or other countries where we operate, or any treaty adopted at the international level to succeed the Kyoto Protocol, that restrict emissions of greenhouse gases could require us to make significant financial expenditures which we cannot predict with certainty at this time.

Because our business depends on the level of activity in the offshore oil and gas industry, existing or future laws, regulations, treaties or international agreements related to greenhouse gases and climate change, including incentives to conserve energy or use alternative energy sources, could have a negative impact on our business if such laws, regulations, treaties or international agreements reduce the worldwide demand for oil and gas. In addition, such laws, regulations, treaties or international agreements could result in increased compliance costs or additional operating restrictions, which may have a negative impact on our business.

Failure to comply with the U.S. Foreign Corrupt Practices Act could result in fines, criminal penalties, drilling contract terminations and an adverse effect on our business.

We currently operate, and historically have operated, our drilling units outside of the United States in a number of countries throughout the world, including some with developing economies. Also, the existence of state or government-owned shipbuilding enterprises puts us in contact with persons who may be considered "foreign officials" under the U.S. Foreign Corrupt Practices Act of 1977, or the FCPA. We are committed to doing business in accordance with applicable anti-corruption laws and have adopted a code of business conduct and ethics which is consistent and in full compliance with the FCPA. We are subject, however, to the risk that we, our affiliated entities or our or their respective officers, directors, employees and agents may take actions determined to be in violation of such anti-corruption laws, including the FCPA. Any such violation could result in substantial fines, sanctions, civil and/or criminal penalties, curtailment of operations in certain jurisdictions, and might adversely affect our business, results of operations or financial condition. In addition, actual or alleged violations could damage our reputation and ability to do business. Furthermore, detecting, investigating, and resolving actual or alleged violations is expensive and can consume significant time and attention of our senior management.

Acts of terrorism and political and social unrest could affect the markets for drilling services, which may have a material adverse effect on our results of operations.

Acts of terrorism and political and social unrest, brought about by world political events or otherwise, have caused instability in the world's financial and insurance markets in the past and may occur in the future. Such acts could be directed against companies such as ours. In addition, acts of terrorism and social unrest could lead to increased volatility in prices for crude oil and natural gas and could affect the markets for drilling services and result in lower dayrates. Insurance premiums could increase and coverage may be unavailable in the future. U.S. government regulations may effectively preclude us from actively engaging in business activities in certain countries. These regulations could be amended to cover countries where we currently operate or where we may wish to operate in the future. Increased insurance costs or increased cost of compliance with applicable regulations may have a material adverse effect on our results of operations.

Military action, other armed conflicts, or terrorist attacks have caused significant increases in political and economic instability in geographic regions where we operate and where our newbuilding drillships are being constructed.

Military tension involving North and South Korea, the Middle East, Africa and other attacks, threats of attacks, terrorism and unrest, have caused instability or uncertainty in the world's financial and commercial markets and have significantly increased political and economic instability in some of the geographic areas where we operate and where we have contracted with Samsung Heavy Industries Co. Ltd., or Samsung, to build our four newbuilding drillships. Acts of terrorism and armed conflicts or threats of armed conflicts in these locations could limit or disrupt our operations, including disruptions resulting from the cancellation of contracts or the loss of personnel or assets. In addition, any possible reprisals as a consequence of ongoing military action in the Middle East, such as acts of terrorism in the United States or elsewhere, could materially and adversely affect us in ways we cannot predict at this time.

Acts of piracy have recently increased in frequency, which could adversely affect our business.

Acts of piracy have historically affected ocean-going vessels trading in regions of the world such as the South China Sea, the Indian Ocean, off the coast of West Africa and in the Gulf of Aden off the coast of Somalia. Although the frequency of sea piracy worldwide decreased during 2012 to its lowest level since 2009, sea piracy incidents continue to occur, particularly in the Gulf of Aden off the coast of Somalia and increasingly in the Gulf of Guinea. If these piracy attacks result in regions in which our drilling units are deployed being characterized as "war risk" zones by insurers, or Joint War Committee "war and strikes" listed areas, premiums payable for such coverage could increase significantly and such insurance coverage may be more difficult to obtain. In addition, crew costs, including due to employing onboard security guards, could increase in such circumstances. We may not be adequately insured to cover losses from these incidents, which could have a material adverse effect on us. In addition, any detention hijacking as a result of an act of piracy against our drilling units, or an increase in cost, or unavailability, of insurance for our vessels, could have a material adverse impact on our business, financial condition and results of operations.

The U.S. government recently imposed legislation concerning the deteriorating situation in Somalia, including acts of piracy offshore Somalia. On April 13, 2010, the President of the United States issued an Executive Order, which we refer to as the Order, prohibiting, among other things, the payment of monies to or for the benefit of individuals and entities on the list of Specially Designated Nationals, or SDNs, published by U.S. Department of the Treasury's Office of Foreign Assets Control. Certain individuals associated with piracy offshore Somalia are currently designated persons under the SDN list. The Order is applicable only to payments by U.S. persons and not by foreign entities, such as Ocean Rig UDW Inc. Notwithstanding this fact, it is possible that the Order, and the regulations promulgated thereunder, may affect foreign private issuers to the extent that such foreign private issuers provide monies, such as ransom payments to secure the release of crews and ships in the event of detention hijackings, to any SDN for which they seek reimbursement from a U.S. insurance carrier. While additional regulations relating to the Order may be promulgated by the U.S. government in the future, we cannot predict what effect these regulations may have on our operations.

Hurricanes may impact our ability to operate our drilling units in the Gulf of Mexico or other U.S. coastal waters, which could reduce our revenues and profitability.

Hurricanes Ivan, Katrina, Rita, Gustav and Ike caused damage to a number of drilling units unaffiliated with us in the U.S. Gulf of Mexico. Drilling units that moved off their locations during the hurricanes damaged platforms, pipelines, wellheads and other drilling units. BOEM and the BSEE, the U.S. organizations that issue a significant number of relevant guidelines for the drilling units' activities, have in place until November 1, 2014 guidelines for tie-downs on drilling units and permanent equipment and facilities attached to outer continental shelf production platforms, and moored drilling unit fitness. These guidelines effectively impose requirements on the offshore oil and natural gas industry in an attempt to increase the likelihood of survival of offshore drilling units during a hurricane. The guidelines also provide for enhanced information and data requirements from oil and natural gas companies that operate properties in the Gulf of Mexico region of the Outer Continental Shelf. BOEM and BSEE may issue similar guidelines for future hurricane seasons and may take other steps that could increase the cost of operations or reduce the area of operations for our ultra-deepwater drilling units, thereby reducing their marketability. Implementation of new guidelines or regulations that may apply to ultra-deepwater drilling units may subject us to increased costs and limit the operational capabilities of our drilling units. Our drilling units do not currently operate in the Gulf of Mexico or other U.S. coastal waters but may do so in the future.

Any failure to comply with the complex laws and regulations governing international trade could adversely affect our operations.

The shipment of goods, services and technology across international borders subjects us to extensive trade laws and regulations. Import activities are governed by unique customs laws and regulations in each of the countries of operation. Moreover, many countries, including the United States, control the export and re-export of certain goods, services and technology and impose related export recordkeeping and reporting obligations. Governments also may impose economic sanctions against certain countries, persons and other entities that may restrict or prohibit transactions involving such countries, persons and entities.

The laws and regulations concerning import activity, export recordkeeping and reporting, export control and economic sanctions are complex and constantly changing. These laws and regulations may be enacted, amended, enforced or interpreted in a manner materially impacting our operations. Shipments can be delayed and denied export or entry for a variety of reasons, some of which are outside our control and some of which may result from failure to comply with existing legal and regulatory regimes. Shipping delays or denials could cause unscheduled operational downtime. Any failure to comply with applicable legal and regulatory trading obligations also could result in criminal and civil penalties and sanctions, such as fines, imprisonment, debarment from government contracts, seizure of shipments and loss of import and export privileges.

New technologies may cause our current drilling methods to become obsolete, resulting in an adverse effect on our business.

The offshore contract drilling industry is subject to the introduction of new drilling techniques and services using new technologies, some of which may be subject to patent protection. As competitors and others use or develop new technologies, we may be placed at a competitive disadvantage and competitive pressures may force us to implement new technologies at substantial cost. In addition, competitors may have greater financial, technical and personnel resources that allow them to benefit from technological advantages and implement new technologies before we can. We may not be able to implement technologies on a timely basis or at a cost that is acceptable to us.

Risks Relating to Our Company

We have substantial indebtedness, and may incur substantial additional indebtedness, which could adversely affect our financial health.

As of December 31, 2012, on a consolidated basis, we had $2.9 billion in aggregate principal amount of indebtedness outstanding and $0 in additional credit available to us under our secured credit facilities. In February 2013, we entered into a $1.35 billion secured term loan facility to partially finance the construction of three of our four ultra-deepwater seventh generation drillships under construction, referred to as our seventh generation drillships, scheduled for delivery in July 2013, October 2013 and November 2013, under which we had $1.35 billion in available borrowing capacity as of the date of this annual report. Our substantial indebtedness could have significant adverse consequences for an investment in us and on our business and future prospects, including the following:

we may not be able to satisfy our financial obligations under our indebtedness and our contractual and commercial commitments, which may result in possible defaults on and acceleration of such indebtedness;

we may not be able to obtain financing in the future for working capital, capital expenditures, acquisitions, debt service requirements or other purposes;

we may not be able to use operating cash flow in other areas of our business because we must dedicate a substantial portion of these funds to service the debt;

we could become more vulnerable to general adverse economic and industry conditions, including increases in interest rates, particularly given our substantial indebtedness, some of which bears interest at variable rates;

our ability to refinance indebtedness may be limited or the associated costs may increase;

less leveraged competitors could have a competitive advantage because they have lower debt service requirements and, as a result, we may not be better positioned to withstand economic downturns;

we may be less able to take advantage of significant business opportunities and to react to changes in market or industry conditions than our competitors and our management's discretion in operating our business may be limited; and

we may be unable to raise the funds necessary to repurchase the 6.50% senior secured notes due 2017, or our Senior Secured Notes, issued by Drill Rigs Holdings Inc., our wholly-owned subsidiary, or Drill Rigs Holdings, in September 2012 tendered to Drill Rigs Holdings if there is a change of control or event of loss or in connection with an asset sale offer, which would constitute a default under the indenture governing the Senior Secured Notes.

Each of these factors may have a material and adverse effect on our financial condition and viability. Our ability to service our debt will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating income is not sufficient to service our current or future indebtedness, we will be forced to take actions such as reducing or delaying our business activities, acquisitions, investments or capital expenditures, selling assets, restructuring or refinancing our debt or seeking additional equity capital. Any or all of these actions may be insufficient to allow us to service our debt obligations. Further, we may not be able to effect any of these remedies on satisfactory terms, or at all.

We may incur additional debt, which could exacerbate the risks associated with our substantial leverage.

Even with our existing level of debt, we and our subsidiaries may incur additional indebtedness in the future. In February 2013, we entered into a $1.35 billion syndicated term loan facility to partially finance the construction costs of three of our seventh generation drillships scheduled for delivery in July 2013, October 2013 and November 2013, and we may incur additional indebtedness in order to fund the estimated remaining contractual obligations, excluding financing costs, of $470.1 million as of the day of this annual report for our fourth seventh generation drillship. Although the terms of our existing debt agreements, and any future debt agreements we enter into, will limit our ability to incur additional debt, these terms may not prohibit us from incurring substantial amounts of additional debt for specific purposes or under certain circumstances. If new debt is added to our and our subsidiaries' current debt levels, the related risks that we and they now face could intensify and could further exacerbate the risks associated with our substantial leverage.

The agreements and instruments governing our indebtedness contain restrictions and limitations that could significantly impact our ability to operate our business.

Our secured credit facilities, the bond agreement governing our unsecured senior notes and the indenture governing the Senior Secured Notes impose, and future financial obligations may impose, certain operating and financial restrictions on us. These restrictions may prohibit or otherwise limit our ability to, among other things:

enter into other financing arrangements;

incur or guarantee additional indebtedness;

create or permit liens on our assets;

consummate a merger, consolidation or sale of our drilling units or the shares of our subsidiaries;

make investments;

change the general nature of our business;

pay dividends, redeem capital stock or subordinated indebtedness or make other restricted payments;

incur dividend or other payment restrictions affecting our restricted subsidiaries under the indenture governing our Senior Secured Notes;

change the management and/or ownership of our drilling units;

enter into transactions with affiliates;

transfer or sell assets;

amend, modify or change our organizational documents;

make capital expenditures; and

compete effectively to the extent our competitors are subject to less onerous restrictions.

In addition, certain of our existing secured credit facilities require us to maintain specified financial ratios and satisfy various financial covenants, including covenants related to the market value of our drilling units, capital expenditures and maintenance of a minimum amount of total available cash. Any future credit agreement or amendment or debt instrument we enter into may contain similar or more restrictive covenants. Events beyond our control, including changes in the economic and business conditions in the deepwater offshore drilling market in which we operate, may affect our ability to comply with these ratios and covenants. Our ability to maintain compliance will also depend substantially on the value of our assets, our dayrates, our ability to obtain drilling contracts, our success at keeping our costs low and our ability to successfully implement our overall business strategy. We cannot guarantee that we would be able to obtain our lenders' waiver or consent with respect to any noncompliance with the specified financial ratios and financial covenants under our various credit facilities or future financial obligations or that we would be able to refinance any such indebtedness in the event of default.

These restrictions, ratios and financial covenants in our debt agreements could limit our ability to fund our operations or capital needs, make acquisitions or pursue available business opportunities, which in turn may adversely affect our financial condition. A violation of any of these provisions could result in a default under our existing and future debt agreements which could allow all amounts outstanding thereunder to be declared immediately due and payable. This would likely in turn trigger cross-acceleration and cross-default rights under the terms of our indebtedness outstanding at such time. If the amounts outstanding under our indebtedness were to be accelerated or were the subject of foreclosure actions, we cannot assure you that our assets would be sufficient to repay in full the money owed to the lenders or to our other debt holders.

We may not be able to generate sufficient cash flow to meet our debt service and other obligations due to events beyond our control.

Our ability to make scheduled payments on our outstanding indebtedness will depend on our ability to generate cash from operations in the future. Our future financial and operating performance will be affected by a range of economic, financial, competitive, regulatory, business and other factors that we cannot control, such as general economic and financial conditions in the offshore drilling industry or the economy generally. In particular, our ability to generate steady cash flow will depend on our ability to secure drilling contracts at acceptable rates. Assuming no exercise of any options to extend the terms of our existing drilling contracts, our operating drilling units are contracted until the fourth quarter of 2014 to the second quarter of 2016. In addition, we have entered into three-year drilling contracts for the Ocean Rig Mylos and the Ocean Rig Athena, our seventh generation drillships scheduled for delivery in July 2013 and November 2013, respectively, which are expected to commence upon delivery of the drillships from the shipyard or to the drilling location, and we have received a letter of award from a major oil company for a three-year drilling contract for the Ocean Rig Apollo, our seventh generation drillship scheduled for delivery in January 2015, to commence upon delivery of the drillship, subject to definitive documentation and customary conditions. Our ability to renew our existing drilling contracts or obtain new drilling contracts at acceptable dayrates upon the expiration of our existing contracts or at all will depend on the prevailing economic and competitive conditions.

Furthermore, our financial and operating performance, and our ability to service our indebtedness, is also dependent on our subsidiaries' ability to make distributions to us, whether in the form of dividends, loans or otherwise. The timing and amount of such distributions will depend on our earnings, financial condition, cash requirements and availability, fleet renewal and expansion, restrictions in our various debt agreements, the provisions of Marshall Islands law affecting the payment of dividends and other factors. Under our two $495.0 million senior secured credit facilities, or the Deutsche Bank credit facilities, the borrowers, Drillship Kithira Owners Inc. and Drillship Skopelos Owners Inc., our wholly-owned subsidiaries, are prohibited from paying dividends and making other distributions to us except following earnings deposit dates and unless all relevant primary transfers, as defined under the credit facilities, have been made, we maintain certain minimum balances in the debt service reserve accounts and no default has occurred, is continuing or will result from the payment. Notwithstanding the foregoing, in the case of the facility for the Ocean Rig Mykonos, distributions may be made upon earnings deposit dates in connection with (i) rebates of Brazilian import taxes incurred prior to May 14, 2012, (ii) the repayment of loans made by us to the borrower in respect of certain capital expenditures and operating expenses incurred prior to May 14, 2012; and (iii) any amounts paid by us following May 14, 2012 in respect of certain capital expenditures and operating expenses in excess of certain budgeted amounts, provided in each case all relevant primary transfers have been made. In addition, under the facility for the Ocean Rig Poseidon, Ocean Rig Poseidon Operations Inc., the borrower and the bareboat charterer, Ocean Rig Poseidon Operations Inc., our wholly-owned subsidiary, are also prohibited from making distributions to us other than out of funds released from the bareboat charter proceeds account during the term of the bareboat charter in respect of the drilling contract with Petrobras Tanzania Limited, or Petrobras Tanzania, for the Ocean Rig Poseidon. Further, Marshall Islands law generally prohibits the payment of dividends other than from surplus or while a company is insolvent or would be rendered insolvent upon the payment of such dividends, or if there is no surplus, dividends may be declared or paid out of net profits for the fiscal year.

If our operating cash flows are insufficient to service our debt and to fund our other liquidity needs, we may be forced to take actions such as reducing or delaying capital expenditures, selling assets, restructuring or refinancing our indebtedness, seeking additional capital, or any combination of the foregoing. We cannot assure you that any of these actions could be effected on satisfactory terms, if at all, or that they would yield sufficient funds to make required payments on our outstanding indebtedness and to fund our other liquidity needs. Also, the terms of existing or future debt agreements may restrict us from pursuing any of these actions. Furthermore, reducing or delaying capital expenditures or selling assets could impair future cash flows and our ability to service our debt in the future.

If for any reason we are unable to meet our debt service and repayment obligations, we would be in default under the terms of the agreements governing such indebtedness, which would allow creditors at that time to declare all such indebtedness then outstanding to be due and payable. This would likely in turn trigger cross-acceleration or cross-default rights among our other debt agreements. Under these circumstances, lenders could compel us to apply all of our available cash to repay borrowings or they could prevent us from making payments on the notes. If the amounts outstanding under our existing and future debt agreements were to be accelerated, or were the subject of foreclosure actions, we cannot assure you that our assets would be sufficient to repay in full the money owed to the lenders or to our other debt holders.

We will need to procure significant additional financing, which may be difficult to obtain on acceptable terms or at all, in order to complete the construction of our seventh generation drillships and any of the other two additional newbuilding drillships for which we exercise our option.

We have newbuilding contracts with Samsung for the construction of four seventh generation ultra-deepwater drillships that are scheduled for delivery in July 2013, October 2013, November 2013 and January 2015, respectively. The estimated total project cost for our four seventh generation drillships, excluding financing costs, is approximately $2.7 billion, of which an aggregate of approximately $1.6 billion was outstanding as of December 31, 2012.

In order to complete the construction of our seventh generation drillships, we will need to procure additional financing. On February 28, 2013, we entered into a $1.35 billion syndicated secured term loan facility to partially finance the construction costs of the Ocean Rig Mylos, the Ocean Rig Skyros and the Ocean Rig Athena, our seventh generation drillships scheduled for delivery in July 2013, October 2013 and November 2013, respectively. We expect to finance the remaining delivery payments for our seventh generation drillships with cash on hand, operating cash flow, equity financing and additional bank debt. We cannot be certain that additional financing will be available on acceptable terms or at all. If additional bank financing is not available when needed, or is available only on unfavorable terms, we may be unable to take delivery of one or more of the seventh generation drillships, in which case we would be prevented from realizing potential revenues from the applicable drillship and we could lose our deposit money, which amounted to $879.4 million in the aggregate, as of December 31, 2012. We may also incur additional costs and liability to the shipyards, which may pursue claims against us under our newbuilding construction contracts and retain and sell our seventh generation drillships to third parties.

In addition, pursuant to an agreement with Samsung, we have the option to construct up to two additional seventh generation, ultra-deepwater drillships, which would be "sister ships" to our seventh generation drillships under construction. The options may be exercised by us at any time on or prior to March 31, 2013, with the optional vessels being delivered on the earliest available delivery dates based on the production schedule, as determined by Samsung in its reasonable discretion, and at a price to be mutually agreed at the time of the option declaration. If we exercise our two newbuilding options, we would expect to incur aggregate additional capital commitments of approximately $1.3 billion, assuming these drillships are built at the same price and with the same specifications as our seventh generation drillships under construction, for which we would be dependent upon obtaining additional financing that we have not yet arranged. Should such financing not be available, this could severely impact our ability to satisfy our liquidity requirements, meet our obligations, finance future obligations and expand the size of our fleet.

We may be unable to secure ongoing drilling contracts, including for the Ocean Rig Skyros and the Ocean Rig Apollo, our two uncontracted seventh generation drillship to be delivered in October 2013 and January 2015, respectively, due to strong competition, and the contracts that we enter into may not provide sufficient cash flow to meet our debt service obligations with respect to our indebtedness.

Assuming no exercise of any options to extend the terms of our existing drilling contracts, our operating drilling units are contracted until the fourth quarter of 2014 to the second quarter of 2016. In addition, we have entered into three-year drilling contracts for the Ocean Rig Mylos and the Ocean Rig Athena, our seventh generation drillships scheduled for delivery in July 2013 and November 2013, respectively, which are expected to commence upon delivery of the drillships from the shipyard or to the drilling location, and we have received a letter of award from a major oil company for a three-year drilling contract for the Ocean Rig Apollo, our seventh generation drillship scheduled for delivery in January 2015, to commence upon delivery of the drillship, subject to definitive documentation and customary conditions. We cannot guarantee that we will enter into definitive documentation for the drilling contract for the Ocean Rig Apollo for which we have received a letter of award or that we will be able to secure employment for the Ocean Rig Skyros, our second seventh generation drillship scheduled for delivery in October 2013.

Our ability to renew our existing drilling contracts or obtain new drilling contracts for our drilling units, including our two seventh generation drillships for which we have not yet secured employment, will depend on prevailing market conditions. We cannot guarantee we will be able to enter into new drilling contracts upon the expiration or termination of the contracts we have in place or at all or that there will not be a gap in employment between our current drilling contracts and subsequent contracts. In particular, if the price of crude oil is low, or it is expected that the price of crude oil will decrease in the future, at a time when we are seeking to arrange employment contracts for our drilling units, we may not be able to obtain employment contracts at attractive rates or at all.

If the rates we receive for the reemployment of our drilling units upon the expiration or termination of our existing drilling contracts are lower than the rates under our existing contracts, we will recognize less revenue from the operations of our drilling units. In addition, delays under existing drilling contracts could cause us to lose future contracts if a drilling unit is not available to start work at the agreed date. Our ability to meet our cash flow obligations will depend on our ability to consistently secure drilling contracts for our drilling units at sufficiently high dayrates. We cannot predict the future level of demand for our services or future conditions in the oil and gas industry. If the oil and gas companies do not continue to increase exploration, development and production expenditures, we may have difficulty securing drilling contracts, including for the seventh generation drillships under construction, or we may be forced to enter into drilling contracts at unattractive dayrates. Either of these events could impair our ability to generate sufficient cash flow to make principal and interest payments under our indebtedness and meet our capital expenditure and other obligations.

Construction of drillships is subject to risks, including delays and cost overruns, which could have an adverse impact on our available cash resources and results of operations.

We have entered into contracts with Samsung for the construction of four seventh generation drillships, the Ocean Rig Mylos, the Ocean Rig Skyros, the Ocean Rig Athena and the Ocean Rig Apollo , which we expect to take delivery of in July 2013, October 2013, November 2013 and January 2015, respectively. From time to time in the future, we may undertake additional new construction projects and conversion projects. Currently, we have options with Samsung for the construction of up to two additional seventh generation ultra-deepwater drillships that we may exercise at any time on or prior to March 31, 2013. In addition, we may make significant upgrade, refurbishment, conversion and repair expenditures for our fleet from time to time, particularly as our drilling units become older. Some of these expenditures are unplanned. These projects together with our existing construction projects and other efforts of this type are subject to risks of cost overruns or delays inherent in any large construction project as a result of numerous factors, including the following:

shipyard unavailability;

shortages of equipment, materials or skilled labor for completion of repairs or upgrades to our equipment;

unscheduled delays in the delivery of ordered materials and equipment or shipyard construction;

financial or operating difficulties experienced by equipment vendors or the shipyard;

unanticipated actual or purported change orders;

local customs strikes or related work slowdowns that could delay importation of equipment or materials;

engineering problems, including those relating to the commissioning of newly designed equipment;

design or engineering changes;

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

work stoppages;

client acceptance delays;

weather interference, storm damage or other events of force majeure;

disputes with shipyards and suppliers;

shipyard failures and difficulties;

failure or delay of third-party equipment vendors or service providers;

unanticipated cost increases; and

difficulty in obtaining necessary permits or approvals or in meeting permit or approval conditions.

These factors may contribute to cost variations and delays in the delivery of our ultra-deepwater newbuilding drillships. Delays in the delivery of these newbuilding drillships or the inability to complete construction in accordance with their design specifications may, in some circumstances, result in a delay in drilling contract commencement, resulting in a loss of revenue to us, and may also cause customers to renegotiate, terminate or shorten the term of a drilling contract for the drillship pursuant to applicable late delivery clauses. In the event of termination of one of these contracts, we may not be able to secure a replacement contract on as favorable terms or at all. Additionally, capital expenditures for drilling unit upgrades, refurbishment and construction projects could materially exceed our planned capital expenditures. Moreover, our drilling units that may undergo upgrade, refurbishment and repair may not earn a dayrate during the periods they are out of service. In addition, in the event of a shipyard failure or other difficulty, we may be unable to enforce certain provisions under our newbuilding contracts such as our refund guarantee, to recover amounts paid as installments under such contracts. The occurrence of any of these events may have a material adverse effect on our results of operations, financial condition or cash flows.

As our current operating fleet is comprised of two ultra-deepwater drilling rigs and four drillships, we rely heavily on a small number of customers and the loss of a significant customer could have a material adverse impact on our financial results.

As of December 31, 2012, we had six customers for our current operating fleet of two ultra-deepwater drilling rigs and four drillships. We are subject to the usual risks associated with having a limited number of customers for our services. Our two largest customers represented 49% and 18% of our revenues during the fiscal year ended December 31, 2012, respectively, and our four customers represented, in the aggregate, 100% of our revenues during the year ended December 31 2012. If our customers terminate, suspend or seek to renegotiate the drilling contracts for drilling units, as they are entitled to do under various circumstances, or cease doing business, our results of operations and cash flows could be adversely affected. Although we expect that a limited number of customers will continue to generate a substantial portion of our revenues, we will have to expand our pool of customers as we take delivery of our four newbuilding drillships and further grow our business.

Currently, our revenues depend on two ultra-deepwater drilling rigs and four drillships, which are designed to operate in harsh environments. The damage or loss of any of our drilling units could have a material adverse effect on our results of operations and financial condition.

Our revenues are dependent on the drilling rig Leiv Eiriksson, which is preparing to commence drilling operations on the Norwegian Continental Shelf, the drilling rig Eirik Raude, which is currently mobilizing to offshore Ireland, where the rig is expected to commence drilling operations, and the drillships Ocean Rig Corcovado and Ocean Rig Mykonos, which are currently operating offshore Brazil, Ocean Rig Olympia, which is currently operating offshore West Africa and Ocean Rig Poseidon, which is currently operating offshore Tanzania. Our drilling units may be exposed to risks inherent in deepwater drilling and operating in harsh environments that may cause damage or loss. The drilling of oil and gas wells, particularly exploratory wells where little is known of the subsurface formations involves risks, such as extreme pressure and temperature, blowouts, reservoir damage, loss of production, loss of well control, lost or stuck drill strings, equipment defects, punch throughs, craterings, fires, explosions, pollution and natural disasters such as hurricanes and tropical storms.

In addition, offshore drilling operations are subject to perils peculiar to marine operations, either while on-site or during mobilization, including capsizing, sinking, grounding, collision, marine life infestations, and loss or damage from severe weather. The replacement or repair of a rig or drillship could take a significant amount of time, and we may not have any right to compensation for lost revenues during that time. As long as we have only six drilling units in operation, loss of or serious damage to one of the drilling units could materially reduce our revenues for the time that drilling unit is out of operation. In view of the sophisticated design of the drilling units, we may be unable to obtain a replacement unit that could perform under the conditions that our drilling units are expected to operate, which could have a material adverse effect on our results of operations and financial condition.

Our future contracted revenue for our fleet of drilling units may not be ultimately realized.

As of March 4, 2013, the future contracted revenue for our fleet of drilling units, or our contract backlog, was approximately $4.4 billion under firm commitments. We may not be able to perform under our drilling contracts due to events beyond our control, and our customers may seek to cancel or renegotiate our drilling contracts for various reasons, including adverse conditions, resulting in lower daily rates. For example, effective March 3, 2013, one of our customers, European Hydrocarbons Limited, or European Hydrocarbons, unilaterally cancelled our drilling contract for the Eirik Raude for drilling offshore West Africa prior to the scheduled termination date. Our inability, or the inability of our customers, to perform under the respective contractual obligations may have a material adverse effect on our financial position, results of operations and cash flows.

We are subject to certain risks with respect to our counterparties, including under our drilling contracts, and failure of these counterparties to meet their obligations could cause us to suffer losses or otherwise adversely affect our business.

We enter into drilling services contracts with our customers, newbuilding contracts with shipyards, interest rate swap agreements and forward exchange contracts, and have employed and may employ our drilling rigs and newbuild drillships on fixed-term and well contracts. Our drilling contracts, newbuilding contracts, and hedging agreements subject us to counterparty risks. The ability of each of our counterparties to perform its obligations under a contract with us will depend on a number of factors that are beyond our control and may include, among other things, general economic conditions, the condition of the offshore contract drilling industry, the overall financial condition of the counterparty, the dayrates received for specific types of drilling rigs and drillships and various expenses. In addition, in depressed market conditions, our customers may no longer need a drilling unit that is currently under contract or may be able to obtain a comparable drilling unit at a lower dayrate. As a result, customers may seek to renegotiate the terms of their existing drilling contracts or avoid their obligations under those contracts. Should a counterparty fail to honor its obligations under an agreement with us, we could sustain significant losses, which could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Most of our offshore drilling contracts may be terminated early due to certain events.

Under most of our current drilling contracts, our customers have the right to terminate the drilling contract upon the payment of an early termination or cancellation fee. However, such payments may not fully compensate us for the loss of the contract. For example, European Hydrocarbons, our customer under our drilling contract for the Eirik Raude for drilling offshore West Africa, unilaterally cancelled the contract effective March 3, 2013, approximately 23 days prior to the contract's scheduled termination date. In connection with the cancellation of the contract, we are entitled to an early termination fee of $13.7 million. As a result of the cancellation, we will not receive approximately $14.1 million in estimated contract revenues, after giving effect to the early termination payment.

In addition, our drilling contracts permit our customers to terminate the contracts early without the payment of any termination fees under certain circumstances, including as a result of major non-performance, longer periods of downtime or impaired performance caused by equipment or operational issues, or sustained periods of downtime due to piracy or force majeure events beyond our control.

In addition, during periods of challenging market conditions, our customers may no longer need a drilling unit that is currently under contract or may be able to obtain a comparable drilling unit at a lower dayrate. As a result, we may be subject to an increased risk of our clients seeking to renegotiate the terms of their existing contracts or repudiate their contracts, including through claims of non-performance. Our customers' ability to perform their obligations under their drilling contracts with us may also be negatively impacted by the prevailing uncertainty surrounding the development of the world economy and the credit markets. If our customers cancel some of our contracts, and we are unable to secure new contracts on a timely basis and on substantially similar terms, or if contracts are suspended for an extended period of time or if a number of our contracts are renegotiated, it could adversely affect our consolidated statement of financial position, results of operations or cash flows.

If our drilling units fail to maintain their class certification or fail any annual survey or special survey, that drilling unit would be unable to operate, thereby reducing our revenues and profitability and violating certain covenants under certain of our debt agreements.

Every drilling unit must be "classed" by a classification society. The classification society certifies that the drilling unit is "in-class," signifying that such drilling unit has been built and maintained in accordance with the rules of the classification society and complies with applicable rules and regulations of the drilling unit's country of registry and the international conventions of which that country is a member. In addition, where surveys are required by international conventions and corresponding laws and ordinances of a flag state, the classification society will undertake them on application or by official order, acting on behalf of the authorities concerned. Both our drilling rigs are certified as being "in class" by Det Norske Veritas. Each of our operating drillships is certified as being "in class" by American Bureau of Shipping. The Leiv Eiriksson was credited with completing its last Special Periodical Survey in April 2011 and the Eirik Raude completed the same in December 2012. Our four operating drillships are due for their first Special Periodical Surveys in 2016. Our seventh generation drillships under construction are due for their first Special Periodical Surveys in 2018. If any drilling unit does not maintain its class and/or fails any annual survey or special survey, the drilling unit will be unable to carry on operations and will be unemployable and uninsurable, which could cause us to be in violation of certain covenants in certain of our debt agreements. Any such inability to carry on operations or be employed, or any such violation of covenants, could have a material adverse impact on our financial condition and results of operations.

Our drilling units, including our seventh generation drillships following their delivery to us, may suffer damage and we may face unexpected yard costs, which could adversely affect our cash flow and financial condition.

If our drilling units, including our seventh generation drillships following their delivery to us, suffer damage, they may need to be repaired at a yard. The costs of yard repairs are unpredictable and can be substantial. The loss of earnings while our drilling units are being repaired and repositioned, as well as the actual cost of these repairs, would decrease our earnings. We may not have insurance that is sufficient to cover all or any of these costs or losses and may have to pay dry docking costs not covered by our insurance.

We may not be able to maintain or replace our drilling units as they age.

The capital associated with the repair and maintenance of our fleet increases with age. We may not be able to maintain our existing drilling units to compete effectively in the market, and our financial resources may not be sufficient to enable us to make expenditures necessary for these purposes or to acquire or build replacement drilling units.

We may have difficulty managing our planned growth properly.

We intend to continue to grow our fleet and we may exercise one or more of our purchase options to purchase up to an additional two newbuilding drillships. Our future growth will primarily depend on our ability to:

locate and acquire suitable drillships;

identify and consummate acquisitions or joint ventures;

enhance our customer base;

locate and retain suitable personnel for our fleet;

manage our expansion; and

obtain required financing on acceptable terms.

Growing any business by acquisition presents numerous risks, such as undisclosed liabilities and obligations, the possibility that indemnification agreements will be unenforceable or insufficient to cover potential losses and difficulties associated with imposing common standards, controls, procedures and policies, obtaining additional qualified personnel, managing relationships with customers and integrating newly acquired assets and operations into existing infrastructure. We may experience operational challenges as we begin operating our new drillships which may result in low earnings efficiency and/or reduced dayrates compared to maximum dayrates. We may be unable to successfully execute our growth plans or we may incur significant expenses and losses in connection with our future growth which would have an adverse impact on our financial condition and results of operations.

The market value of our current drilling units, and any drilling units we may acquire in the future, including our seventh generation drillships upon their delivery to us, may decrease, which could cause us to incur losses if we decide to sell them following a decline in their values or accounting charges that may affect our ability to comply with certain covenants in our secured credit facilities.

If the offshore contract drilling industry suffers adverse developments in the future, the fair market value of our drilling units may decline. The fair market value of the drilling units we currently own or may acquire in the future may increase or decrease depending on a number of factors, including:

prevailing level of drilling services contract dayrates;

general economic and market conditions affecting the offshore contract drilling industry, including competition from other offshore contract drilling companies;

types, sizes and ages of drilling units;

supply and demand for drilling units;

costs of newbuildings;

governmental or other regulations; and

technological advances.

In the future, if the market values of our drilling units deteriorate significantly, we may be required to record an impairment charge in our financial statements, which could adversely affect our results of operations. If we sell any drilling unit when drilling unit prices have fallen and before we have recorded an impairment adjustment to our financial statements, the sale may be at less than the drilling unit's carrying amount on our financial statements, resulting in a loss. Additionally, any such deterioration in the market values of our drilling units could trigger a breach of certain financial covenants under our secured credit facilities and our lenders may accelerate loan repayments. Such a charge, loss or repayment could materially and adversely affect our business prospects, financial condition, liquidity, and results of operations.

Because we generate most of our revenues in U.S. Dollars, but incur a significant portion of our employee salary and administrative and other expenses in other currencies, exchange rate fluctuations could have an adverse impact on our results of operations.

Our principal currency for our operations and financing is the U.S. Dollar. A substantial portion of the operating dayrates for the drilling units, our principal source of revenues, are quoted and received in U.S. Dollars; however, a portion of our revenue under our contracts with Petróleo Brasileiro S.A., or Petrobras Brazil, for the Ocean Rig Corcovado and the Ocean Rig Mykonos is, and a portion of our revenue under our contract with Repsol Sinopec Brasil S.A., or Repsol, for the Ocean Rig Mylos, our seventh generation drillship scheduled to be delivered in July 2013 will be, receivable in Brazilian Real. The principal currency for operating expenses is also the U.S. Dollar; however, a significant portion of employee salaries and administration expenses, as well as parts of the consumables and repair and maintenance expenses for the drilling rigs, may be paid in Norwegian Kroner (NOK), Great British Pounds (GBP), Canadian dollars (CAD), Euros (EUR) or other currencies depending in part on the location of our drilling operations. For the year ended December 31, 2012, approximately 61% of our expenses were incurred in currencies other than the U.S. Dollars. This exposure to foreign currency could lead to fluctuations in net income and net revenue due to changes in the value of the U.S. Dollar relative to the other currencies. Revenues paid in foreign currencies against which the U.S. Dollar rises in value can decrease, resulting in lower U.S. Dollar denominated revenues. Expenses incurred in foreign currencies against which the U.S. Dollar falls in value can increase, resulting in higher U.S. Dollar denominated expenses. We have employed derivative instruments in order to economically hedge our currency exposure; however, we may not be successful in hedging our future currency exposure and our U.S. Dollar denominated results of operations could be materially and adversely affected upon exchange rate fluctuations determined by events outside of our control.

We are dependent upon key management personnel.

Our operations depend to a significant extent upon the abilities and efforts of our key management personnel. The loss of our key management personnel's service to us could adversely affect our efforts to obtain employment for our drillships and discussions with our lenders and, therefore, could adversely affect our business prospects, financial condition and results of operations. We do not currently, nor do we intend to, maintain "key man" life insurance on any of our personnel.

Failure to attract or retain key personnel, labor disruptions or an increase in labor costs could adversely affect our operations.

We require highly skilled personnel to operate and provide technical services and support for our business in the offshore drilling sector worldwide. As of December 31, 2012, we employed 1,374 employees, the majority of whom are full-time crew employed on our drilling units. Under certain of our employment contracts, we are required to have a minimum number of local crew members on our drillships. We will need to recruit additional qualified personnel as we take delivery on our newbuilding drillships. Competition for the labor required for drilling operations has intensified as the number of rigs activated, added to worldwide fleets or under construction has increased, leading to shortages of qualified personnel in the industry and creating upward pressure on wages and higher turnover. If turnover increases, we could see a reduction in the experience level of our personnel, which could lead to higher downtime, more operating incidents and personal injury and other claims, which in turn could decrease revenues and increase costs. In response to these labor market conditions, we are increasing efforts in our recruitment, training, development and retention programs as required to meet our anticipated personnel needs. If these labor trends continue, we may experience further increases in costs or limits on our offshore drilling operations.

Currently, none of our employees are covered by collective bargaining agreements. In the future, some of our employees or contracted labor may be covered by collective bargaining agreements in certain jurisdictions such as Brazil, Nigeria, Norway and the United Kingdom. As part of the legal obligations in some of these agreements, we may be required to contribute certain amounts to retirement funds and pension plans and have restricted ability to dismiss employees. In addition, many of these represented individuals could be working under agreements that are subject to salary negotiation. These negotiations could result in higher personnel costs, other increased costs or increased operating restrictions that could adversely affect our financial performance. Labor disruptions could hinder our operations from being carried out normally and if not resolved in a timely cost-effective manner, could have a material impact our business. If we choose to cease operations in one of those countries or if market conditions reduce the demand for our drilling services in such a country, we would incur costs, which may be material, associated with workforce reductions.

Our operating and maintenance costs with respect to our offshore drilling units will not necessarily fluctuate in proportion to changes in operating revenues, which may have a material adverse effect on our results of operations, financial condition and cash flows.

Operating revenues may fluctuate as a function of changes in supply of offshore drilling units and demand for contract drilling services, which, in turn, affect dayrates and the utilization and performance of our drilling units. However, costs for operating drilling units are generally fixed regardless of the dayrate being earned. Therefore, our operating and maintenance costs with respect to our offshore drilling units will not necessarily fluctuate in proportion to changes in operating revenues. In addition, should our drilling units incur idle time between contracts, we typically will not de-man those drilling units but rather use the crew to prepare the units for its next contract. During times of reduced activity, reductions in costs may not be immediate, as portions of the crew may be required to prepare rigs for stacking, after which time the crew members are assigned to active rigs or dismissed. In addition, as our drilling units are mobilized from one geographic location to another, labor and other operating and maintenance costs can vary significantly. In general, labor costs increase primarily due to higher salary levels and inflation. Equipment maintenance expenses fluctuate depending upon the type of activity the unit is performing and the age and condition of the equipment. Contract preparation expenses vary based on the scope and length of contract preparation required and the duration of the firm contractual period over which such expenditures are incurred. If we experience increased operating costs without a corresponding increase in earnings, this may have a material adverse effect on our results of operations, financial condition and cash flows.

In the event Samsung does not perform under its agreements with us and we are unable to enforce certain refund guarantees, we may lose all or part of our investment, which would have a material adverse effect on our results of operations, financial condition and cash flows.

As of December 31, 2012, we had paid an aggregate of $879.4 million to Samsung in connection with our seventh generation drillships currently scheduled for delivery in July 2013, October 2013, November 2013 and January 2015. The remaining total construction payments for these four newbuilding drillships, excluding financing costs, amounted to approximately $1.6 billion in the aggregate as of December 31, 2012.

In addition, we have options under our contract with Samsung to construct up to two additional seventh generation, ultra-deepwater drillships, which would be sister-ships to our seventh generation drillships. The deadline for exercising these options is March 31, 2013, with the option vessels, if exercised, being delivered on the earliest available delivery dates based on the production schedule, as determined by Samsung in its reasonable discretion, and at a price to be mutually agreed at the time of the option declaration. In the event Samsung does not perform under its agreements with us and we are unable to enforce certain refund guarantees with third party bankers due to an outbreak of war, bankruptcy or otherwise, we may lose all or part of our investment, which would have a material adverse effect on our results of operations, financial condition and cash flows.

The derivative contracts we have entered into to hedge our exposure to fluctuations in interest rates could result in higher than market interest rates and charges against our income.

As of December 31, 2012, we had entered into interest rate swaps for the purpose of managing our exposure to fluctuations in interest rates applicable to indebtedness under our secured credit facilities, which was drawn at a floating rate based on LIBOR. Our hedging strategies, however, may not be effective and we may incur substantial losses if interest rates move materially differently from our expectations. Our existing interest rate swaps as of December 31, 2012 do not, and future derivative contracts may not, qualify for treatment as hedges for accounting purposes. We recognize fluctuations in the fair value of these contracts in our statement of operations. In addition, our financial condition could be materially adversely affected to the extent we do not hedge our exposure to interest rate fluctuations under our financing arrangements, under which loans have been advanced at a floating rate based on LIBOR and for which we have not entered into an interest rate swap or other hedging arrangement. Any hedging activities we engage in may not effectively manage our interest rate exposure or have the desired impact on our financial conditions or results of operations. At December 31, 2012, the fair value of our interest rate swaps was in a net liability position of $76.7 million.

An increase in interest rates would increase the cost of servicing our indebtedness and could reduce our profitability.

Our debt under certain of our senior secured credit facilities bears interest at variable rates. We may also incur indebtedness in the future with variable interest rates. As a result, an increase in market interest rates would increase the cost of servicing our indebtedness and could materially reduce our profitability and cash flows. The impact of such an increase would be more significant for us than it would be for some other companies because of our substantial indebtedness.

A change in tax laws, treaties or regulations, or their interpretation, of any country in which we operate could result in a higher tax rate on our worldwide earnings, which could result in a significant negative impact on our earnings and cash flows from operations.

We conduct our worldwide drilling operations through various subsidiaries. Tax laws and regulations are highly complex and subject to interpretation. Consequently, we are subject to changing tax laws, treaties and regulations in and between countries in which we operate. Our income tax expense is based upon our interpretation of tax laws in effect in various countries at the time that the expense was incurred. A change in these tax laws, treaties or regulations, or in the interpretation thereof, or in the valuation of our deferred tax assets, could result in a materially higher tax expense or a higher effective tax rate on our worldwide earnings, and such change could be significant to our financial results. If any tax authority successfully challenges our operational structure, inter-company pricing policies or the taxable presence of our operating subsidiaries in certain countries; or if the terms of certain income tax treaties are interpreted in a manner that is adverse to our structure; or if we lose a material tax dispute in any country, particularly in the United States, Canada, the U.K., Brazil, Turkey, Angola, Cyprus, Korea, Ghana, Netherlands, Ivory Coast, Tanzania, Falkland Islands or Norway, our effective tax rate on our worldwide earnings could increase substantially and our earnings and cash flows from our operations could be materially adversely affected.

Our subsidiaries are subject to taxation in the jurisdictions in which their offshore drilling activities are conducted. Such taxation results in decreased earnings available to our shareholders.

United States tax authorities may treat us as a "passive foreign investment company" for United States federal income tax purposes, which may have adverse tax consequences to U.S. shareholders.

A foreign corporation will be treated as a "passive foreign investment company," or PFIC, for U.S. federal income tax purposes if either (1) at least 75% of its gross income for any taxable year consists of certain types of "passive income" or (2) at least 50% of the average value of the corporation's assets produce or are held for the production of those types of "passive income". For purposes of these tests, "passive income" includes dividends, interest, and gains from the sale or exchange of investment property and rents and royalties other than rents and royalties which are received from unrelated parties in connection with the active conduct of a trade or business. For purposes of these tests, income derived from the performance of services does not constitute "passive income." U.S. shareholders of a PFIC are subject to a disadvantageous U.S. federal income tax regime with respect to the income derived by the PFIC, the distributions they receive from the PFIC and the gain, if any, they derive from the sale or other disposition of their shares in the PFIC.

We do not believe that we are currently a PFIC, although certain of our wholly-owned subsidiaries may have been classified as PFICs at any time through the conclusion of the 2008 taxable year. Based on our current operations and future projections, we do not believe that we or any of our subsidiaries have been, are or will be a PFIC with respect to any taxable year beginning with the 2009 taxable year.

However, no assurance can be given that the U.S. Internal Revenue Service, or IRS, or a court of law will accept our position, and there is a risk that the IRS or a court of law could determine that we or one of our subsidiaries is a PFIC. Moreover, no assurance can be given that we or one of our subsidiaries would not constitute a PFIC for any future taxable year if there were to be changes in the nature and extent of its operations.

If the IRS were to find that we are or have been a PFIC for any taxable year, our U.S. shareholders will face adverse U.S. tax consequences. Under the PFIC rules, unless those shareholders make an election available under the Code (which election could itself have adverse consequences for such shareholders, as discussed below under "Taxation—U.S. Federal Income Tax Considerations"), such shareholders would be liable to pay U.S. federal income tax at the then prevailing income tax rates on ordinary income plus interest upon excess distributions and upon any gain from the disposition of the common shares, as if the excess distribution or gain had been recognized ratably over the shareholder's holding period of the common shares. In the event that our shareholders face adverse U.S. tax consequences as a result of investing in our common shares, this could adversely affect our ability to raise additional capital through the equity markets. See "Taxation—U.S. Federal Income Tax Considerations" for a more comprehensive discussion of the U.S. federal income tax consequences to U.S. shareholders if we are treated as a PFIC.

We may be subject to litigation that, if not resolved in our favor and not sufficiently insured against, could have a material adverse effect on us.

We may be, from time to time, involved in various litigation matters. These matters may include, among other things, contract disputes, personal injury claims, environmental claims or proceedings, asbestos and other toxic tort claims, employment matters, governmental claims for taxes or duties, and other litigation that arises in the ordinary course of our business. We cannot predict with certainty the outcome or effect of any claim or other litigation matter, and the ultimate outcome of any litigation or the potential costs to resolve them may have a material adverse effect on us. Insurance may not be applicable or sufficient in all cases, insurers may not remain solvent and policies may not be located.

Investor confidence may be adversely impacted if we are unable to comply with Section 404 of the Sarbanes-Oxley Act of 2002.

We have implemented procedures in order to meet the evaluation requirements of Rules 13a-15(c) and 15d-15(c) under the Securities Exchange Act of 1934, or the Exchange Act, for the assessment under Section 404 of the Sarbanes-Oxley Act of 2002, or Section 404. Section 404 requires us to include in our annual reports on Form 20-F (i) our management's report on, and assessment of, the effectiveness of our internal controls over financial reporting and (ii) our independent registered public accounting firm's attestation to and report on the effectiveness of our internal controls over financial reporting in our annual report. If we fail to maintain the adequacy of our internal controls over financial reporting, we will not be in compliance with all of the requirements imposed by Section 404. Any failure to comply with Section 404 could result in an adverse reaction in the financial marketplace due to a loss of investor confidence in the reliability of our financial statements, which ultimately could harm our business.

We and many of our subsidiaries are incorporated in the Republic of the Marshall Islands, which does not have a well-developed body of corporate law, and as a result, shareholders may have fewer rights and protections under Marshall Islands law than under a typical jurisdiction in the United States.

Our corporate affairs are governed by our second amended and restated articles of incorporation and second amended and restated bylaws and by the Marshall Islands Business Corporations Act, or the BCA. The provisions of the BCA resemble provisions of the corporation laws of a number of states in the United States. However, there have been few judicial cases in the Republic of the Marshall Islands interpreting the BCA. The rights and fiduciary responsibilities of directors under the law of the Republic of the Marshall Islands are not as clearly established as the rights and fiduciary responsibilities of directors under statutes or judicial precedent in existence in certain United States jurisdictions. Shareholders' rights may differ as well. While the BCA does specifically incorporate the non-statutory law, or judicial case law, of the State of Delaware and other states with substantially similar legislative provisions, shareholders may have more difficulty in protecting their interests in the face of actions by management, directors or controlling shareholders than would shareholders of a corporation incorporated in a United States jurisdiction.

It may not be possible for investors to enforce U.S. judgments against us.

We and all but one of our subsidiaries are incorporated in jurisdictions outside the United States and a substantial portion of our assets and those of our subsidiaries are located outside the United States. In addition, all of our directors and officers reside outside the United States and a substantial portion of the assets of our directors and officers are located outside the United States. As a result, it may be difficult or impossible for U.S. investors to serve process within the United States upon us, our subsidiaries or our directors and officers or to enforce a judgment against us for civil liabilities in U.S. courts. In addition, you should not assume that courts in the countries in which we or our subsidiaries are incorporated or where our assets or the assets of our subsidiaries and directors and officers are located (i) would enforce judgments of U.S. courts obtained in actions against us or our subsidiaries and directors and officers based upon the civil liability provisions of applicable U.S. federal and state securities laws or (ii) would enforce, in original actions, liabilities against us or our subsidiaries and directors and officers based on those laws.

We depend on officers and directors who are associated with affiliated companies which may create conflicts of interest.

Our officers and directors have fiduciary duties to manage our business in a manner beneficial to us and our shareholders. However, our Chairman, President and Chief Executive Officer, Mr. George Economou, is also the Chairman, President and Chief Executive Officer of DryShips, our parent company, and has significant shareholdings in DryShips. In addition, our Executive Vice President, Mr. Anthony Kandylidis, is the son of a director of DryShips and the nephew of our Chairman, President and Chief Executive Officer. Mr. Economou has fiduciary duties to manage the business of DryShips in a manner beneficial to DryShips and its shareholders and may have conflicts of interest in matters involving or affecting us and our customers or shareholders. In addition, Messrs. Economou and Kandylidis may have conflicts of interest when faced with decisions that could have different implications for DryShips than they do for us. The resolution of these conflicts may not always be in our best interest or that of our shareholders and could have a material adverse effect on our business, results of operations, cash flows and financial condition.

In addition, we have engaged Cardiff Drilling (formerly known as Cardiff Oil & Gas Management Inc.) to provide consulting and other services relating to our drilling units. The capital stock of Cardiff Drilling is owned Mr. Economou. We have also engaged Vivid Finance Ltd., or Vivid Finance, a company controlled by Mr. Economou, to act as a consultant on financing matters relating to us and our subsidiaries. If any of these conflicts of interest are not resolved in our favor, this could have a material adverse effect on our business.

Furthermore, the indenture governing our Senior Secured Notes contains restrictions our ability and the ability of our Restricted Subsidiaries (as defined in the indenture), including Drill Rigs Holdings, the issuer of the Senior Secured Notes, to engage in transactions with, or make certain payments to, affiliates. These restrictions do not prohibit us or any Restricted Subsidiary from entering into a management agreement with an affiliate, including DryShips and any of its subsidiaries, for the provision of drilling unit management services (and the making of payments thereunder) that is entered into in the ordinary course of business and that is in line with industry standards, so long as such agreement has been approved by a majority of the disinterested directors.

Because the Public Company Accounting Oversight Board is not currently permitted to inspect our independent accounting firm, you may not benefit from such inspections.

Auditors of U.S. public companies are required by law to undergo periodic Public Company Accounting Oversight Board, PCAOB, inspections that assess their compliance with U.S. law and professional standards in connection with performance of audits of financial statements filed with the SEC. Certain European Union countries, including Greece, do not currently permit the PCAOB to conduct inspections of accounting firms established and operating in such European Union countries, even if they are part of major international firms. Accordingly, unlike for most U.S. public companies, the PCAOB is prevented from evaluating our auditor's performance of audits and its quality control procedures, and, unlike stockholders of most U.S. public companies, we and our stockholders are deprived of the possible benefits of such inspections.

We may be adversely affected by the introduction of new accounting rules for leasing.

International and U.S. accounting standard-setting boards (the International Accounting Standards Board, or IASB, and the Financial Accounting Standards Board, or FASB) have proposed changes to the accounting for operating and finance leases. If the proposals are adopted, they would be expected generally to have the effect of bringing most off-balance sheet leases onto a lessee's balance sheet as liabilities which would also change the income and expense recognition patterns of those items. Financial statement metrics, such as leverage and capital ratios, as well as EBITDA, may also be affected, even when cash flow and business activity have not changed. This may in turn affect covenant calculations under various contracts (e.g., loan agreements) unless the affected contracts are modified. The IASB and FASB are reconsidering their original proposals to address concerns raised by constituents and expect to issue revised proposals in the first quarter of 2013. Accordingly, the timing and ultimate effect of those proposals on the Company is uncertain.

Risks Relating to Our Common Shares

We cannot assure you that an active and liquid public market for our common shares will continue.

Our common shares commenced "regular way" trading on the NASDAQ Global Select Market on October 6, 2011 and commenced trading in the Norwegian OTC market maintained by the Norwegian Security Dealers Association in December 2010. We cannot assure you that an active and liquid public market for our common shares will continue.

Since 2008, the U.S. stock market has experienced extreme price and volume fluctuations. In addition, the offshore drilling industry has been highly unpredictable and volatile. If the volatility in the market or the offshore drilling industry continues or worsens, it could have an adverse effect on the market price of our common stock and may impact a potential sale price if holders of our common stock decide to sell their shares.

The market price of our common stock may be influenced by many factors, many of which are beyond our control, including those described above in "—D. Risk Factors" and the following:

actual or anticipated variations in our operating results;

changes in our cash flow, EBITDA or earnings estimates;

changes in the price of oil;

publication of research reports about us or the industry in which we operate;

increases in market interest rates that may lead purchasers of common shares to demand a higher expected yield which, would mean our share price would fall;

changes in applicable laws or regulations, court rulings and enforcement and legal actions;

changes in market valuations of similar companies;

announcements by us or our competitors of significant contracts, acquisitions or capital commitments;

adverse market reaction to any increased indebtedness we incur in the future;

additions or departures of key personnel;

actions by institutional stockholders;

speculation in the press or investment community;

terrorist attacks;

economic and regulatory trends; and

general market conditions.

As a result of these and other factors, investors in our common stock may not be able to resell their shares at or above the price they paid for such shares or at all. These broad market and industry factors may materially reduce the market price of our common stock, regardless of our operating performance.

Future sales of our common shares could have an adverse effect on our share price.

In order to finance the currently contracted and future growth of our fleet, we will have to incur substantial additional indebtedness and possibly issue additional equity securities. Future common share issuances, directly or indirectly through convertible or exchangeable securities, options or warrants, will generally dilute the ownership interests of our existing common stockholders, including their relative voting rights, and could require substantially more cash to maintain the then existing level, if any, of our dividend payments to our common stockholders, as to which no assurance can be given. Preferred shares, if issued, will generally have a preference on dividend payments, which could prohibit or otherwise reduce our ability to pay dividends to our common stockholders. Our debt will be senior in all respects to our common shares, will generally include financial and operating covenants with which we must comply and will include acceleration provisions upon defaults thereunder, including our failure to make any debt service payments, and possibly under other debt. Because our decision to issue equity securities or incur debt in the future will depend on a variety of factors, including market conditions and other matters that are beyond our control, we cannot predict or estimate the timing, amount or form of our capital raising activities in the future. Such activities could, however, cause the price of our common shares to decline significantly.

As of March 20, 2013, DryShips owned 78,301,755, or approximately 59.4%, of our outstanding common shares, our Chairman, President and Chief Executive Officer, Mr. George Economou, was deemed to beneficially own 5,393,289, or approximately 4.1% of our outstanding common shares and our Executive Vice President, Mr. Anthony Kandylidis, was deemed to beneficially own 1,684,512, or 1.3%, of our outstanding common shares. The common shares held by DryShips and beneficially owned by Mr. Economou are "restricted securities" within the meaning of Rule 144 under the U.S. Securities Act of 1933, as amended, or the Securities Act, and may not be transferred unless they have been registered under the Securities Act or an exemption from registration is available. Upon satisfaction of certain conditions, Rule 144 permits the sale of certain amounts of restricted securities six months following the date of acquisition of the restricted securities from us. As our common shares become eligible for sale under Rule 144, the volume of sales of our common shares on applicable securities markets may increase, which could reduce the market value of our common shares.

DryShips, our parent company, controls the outcome of matters on which our shareholders are entitled to vote.

As of March 20, 2013, DryShips owned approximately 59.4%, of our outstanding common shares. DryShips will control the outcome of matters on which our shareholders are entitled to vote, including the election of directors and other significant corporate actions. DryShips's interests may be different from your interests and the commercial goals of DryShips as a shareholder, and our goals, may not always be aligned. The substantial equity interests owned by DryShips may make it more difficult for us to maintain our business independence from other companies owned by DryShips and DryShips's affiliates.

Anti-takeover provisions contained in our organizational documents could make it difficult for our shareholders to replace or remove our current board of directors or have the effect of discouraging, delaying or preventing a merger or acquisition, which could adversely affect the market price of our securities.

Several provisions of our second amended and restated articles of incorporation and second amended and restated bylaws could make it difficult for our shareholders to change the composition of our board of directors in any one year, preventing them from changing the composition of management. In addition, the same provisions may discourage, delay or prevent a merger or acquisition that shareholders may consider favorable.

These provisions include:

authorizing our board of directors to issue "blank check" preferred shares without shareholder approval;

providing for a classified board of directors with staggered, three-year terms;

prohibiting cumulative voting in the election of directors;

authorizing the removal of directors only for cause and only upon the affirmative vote of the holders of a majority of the outstanding common shares entitled to vote generally in the election of directors;

limiting the persons who may call special meetings of shareholders ; and

establishing advance notice requirements for nominations for election to our board of directors or for proposing matters that can be acted on by shareholders at shareholder meetings.

In addition, we entered into an Amended and Restated Stockholder Rights Agreement that makes it more difficult for a third party to acquire us without the support of our board of directors. Under the Amended and Restated Stockholder Rights Agreement, our board of directors declared a dividend of one preferred share purchase right, or a right, to purchase one one-thousandth of a share of our Series A Participating Preferred Shares for each of our outstanding common shares. Each right entitles the registered holder, upon the occurrence of certain events, to purchase from us one one-thousandth of a share of Series A Participating Preferred Shares. The rights may have anti-takeover effects. The rights will cause substantial dilution to any person or group that attempts to acquire us without the approval of our board of directors. As a result, the overall effect of the rights may be to render more difficult or discourage any attempt to acquire us. Because our board of directors will be able to approve a redemption of the rights or a permitted offer, the rights should not interfere with a merger or other business combination approved by our board of directors.

Although the BCA does not contain specific provisions regarding "business combinations" between corporations organized under the laws of the Republic of Marshall Islands and "interested shareholders," our second amended and restated articles of incorporation include provisions that prohibit us from engaging in a business combination with an interested shareholder for a period of three years after the date of the transaction in which the person became an interested shareholder, unless:

prior to the date of the transaction in which the person became an interested shareholder, our board of directors approved either the business combination or the transaction which resulted in the shareholder becoming an interested shareholder;

upon consummation of the transaction that resulted in the shareholder becoming an interested shareholder, the interested shareholder owned at least 85% of our voting stock outstanding at the time the transaction commenced;

at or subsequent to the date of the transaction that resulted in the shareholder becoming an interested shareholder, the business combination is approved by the board of directors and authorized at an annual or special meeting of shareholders by the affirmative vote of at least 66 2/3% of the outstanding voting stock that is not owned by the interested shareholder; or

the shareholder became an interested shareholder prior to the consummation of our initial public offering under the Securities Act.

For purposes of these provisions, a "business combination" includes mergers, consolidations, exchanges, asset sales, leases and other transactions resulting in a financial benefit to the interested shareholder and an "interested shareholder" is any person or entity that beneficially owns 15% or more of our outstanding voting stock and any person or entity affiliated with or controlling or controlled by that person or entity, other than DryShips, provided, however, that the term "interested shareholder" does not include any person whose ownership of shares in excess of the 15% limitation is the result of action taken solely by us; provided that such person shall be an interested shareholder if thereafter such person acquires additional shares of our voting shares, except as a result of further action by us not caused, directly or indirectly, by such person. Further, the term "business combination", when used in reference to us and any "interested shareholder" does not include any transactions for which definitive agreements were entered into prior to May 3, 2011, the date the second amended and restated articles of incorporation were filed with the Republic of the Marshall Islands.

Item 4. Information on the Company

A. History and Development of the Company

Ocean Rig UDW Inc., a corporation organized under the laws of the Republic of the Marshall Islands, was formed on December 10, 2007 under the name Primelead Shareholders Inc. Primelead Shareholders Inc. was formed in December 2007 for the purpose of acquiring the shares of our predecessor, Ocean Rig ASA, which was incorporated in September 1996 under the laws of Norway. We acquired control of Ocean Rig ASA on May 14, 2008. Prior to the private offering of our common shares in December 2010, discussed below, we were a wholly-owned subsidiary of DryShips. Our shares commenced trading on the NASDAQ Global Select Market under the symbol "ORIG" on October 6, 2011. As of March 20, 2013, DryShips, our parent company, owned approximately 59.4% of our outstanding common shares. Each of our drilling units is owned by a separate wholly-owned vessel-owning subsidiary.

We maintain our principal executive offices at 10 Skopa Street, Tribune House, 2nd Floor, Office 202, CY 1075, Nicosia, Cyprus and our telephone number at that address is +357 22767517. Our website address is www.ocean-rig.com. Information contained on our website does not constitute part of this annual report.

Business Development

In March 2009, DryShips contributed to us all of its equity interests in the newbuilding vessel-owning companies of the Ocean Rig Poseidon and Ocean Rig Mykonos. In May 2009, we acquired the equity interests of Drillships Holdings Inc., the owner of the Ocean Rig Corcovado and the Ocean Rig Olympia, from third parties and entities affiliated with our Chairman, President and Chief Executive Officer and, in exchange, we issued to the sellers common shares equal to 25% of our total issued and outstanding common shares as of May 15, 2009. In July 2009, DryShips acquired the remaining 25% of our total issued and outstanding capital stock from the minority interests held by third parties and entities controlled by our Chairman, President and Chief Executive Officer for a $50.0 million cash payment and the issuance of Series A Convertible Preferred Shares of DryShips with an aggregate face value of $280.0 million, following which we became a wholly-owned subsidiary of DryShips.

On December 21, 2010, we completed the sale of an aggregate of 28,571,428 of our common shares (representing approximately 22% of our then outstanding common shares) in an offering made to both non-U.S. persons in Norway in reliance on Regulation S under the Securities Act and to qualified institutional buyers in the United States in reliance on Rule 144A under the Securities Act at a price of $17.50 per share, or the 2010 Private Offering. A company controlled by our Chairman, President and Chief Executive Officer, Mr. Economou, purchased 2,869,428 common shares, or 2.38% of our outstanding common shares, in the 2010 Private Offering at the offering price of $17.50 per share. Following the completion of the 2010 Private Offering, DryShips owned approximately 78% of our outstanding common shares.

On April 27, 2011, we completed the issuance of $500.0 million aggregate principal amount of 9.5% senior unsecured notes due 2016 offered in a private offering to eligible purchasers, or the 2011 Unsecured Bond Offering.

On August 26, 2011, we commenced an offer to exchange up to 28,571,428 shares of our new common stock that were registered under the Securities Act pursuant to a registration statement on Form F-4 (Registration No. 333-175940), for an equivalent number of our common shares previously sold in the 2010 Private Offering, or the Exchange Offer. On September 29, 2011, an aggregate of 28,505,786 common shares were exchanged in the Exchange Offer.

On October 5, 2011, DryShips completed the partial spin off of us by distributing an aggregate of 2,967,291 of our common shares, representing approximately a 2.25% stake in us, after giving effect to the treatment of fractional shares, on a pro rata basis to DryShips's shareholders of record as of September 21, 2011. In lieu of fractional shares, DryShips's transfer agent aggregated all fractional shares that would otherwise be distributable to DryShips's shareholders and sold a total of 105 common shares on behalf of those shareholders who would otherwise be entitled to receive a fractional share of our Company. Following the distribution, each such shareholder received a cash payment in an amount equal to its pro rata share of the total net proceeds of the sale of fractional shares. On September 19, 2011, our common shares commenced "when issued" trading on the NASDAQ Global Select Market under the ticker "ORIGV." Our common shares commenced "regular way" trading on the NASDAQ Global Select Market under the ticker symbol "ORIG" on October 6, 2011.

On November 3, 2011, the merger of Pelican Stockholdings Inc., a wholly-owned subsidiary of DryShips, and OceanFreight was completed, following approval by shareholders of OceanFreight at a special meeting of shareholders held on November 3, 2011. Following the completion of the merger, OceanFreight is a wholly-owned subsidiary of DryShips. We refer to this transaction as the OceanFreight merger. Under the terms of the merger agreement, OceanFreight shareholders received $11.25 cash and 0.52326 of a share of our common stock per share of OceanFreight common stock previously owned. Our common shares that comprised the stock portion of the merger consideration were previously outstanding shares that were owned by DryShips. Following the closing of the merger, DryShips transferred $33.1 million in cash and 1,541,159 shares of our common shares to shareholders of OceanFreight, other than the entities controlled by Mr. Anthony Kandylidis, the Chief Executive Officer of OceanFreight and our Executive Vice President. Prior to the completion of the merger, DryShips acquired from entities controlled by Mr. Kandylidis all of their shares of OceanFreight, representing a majority of the then outstanding shares of OceanFreight, for the same consideration per share that the OceanFreight shareholders received in the OceanFreight merger, the equity portion of which consisted of an aggregate of 1,570,226 of our common shares.

On April 17, 2012, DryShips completed the public offering of an aggregate of 11,500,000 of our common shares owned by DryShips. Companies affiliated with our Chairman, President and Chief Executive Officer purchased a total of 2,185,000 common shares from DryShips at the public offering price of $16.25 per share.

On September 20, 2012, Drill Rigs Holdings, our wholly-owned subsidiary, completed the issuance of $800 million of aggregate principal amount of Senior Secured Notes in an offering made to both non-U.S. persons in reliance on Regulation S under the Securities Act and to qualified institutional buyers in the United States in reliance on Rule 144A under the Securities Act, or the 2012 Secured Bond Offering.

On February 14, 2013, DryShips completed the public offering of an aggregate of 7,500,000 of our common shares owned by DryShips.

Capital Expenditures

During the years ended December 31, 2010 and 2011, our principal capital expenditures related to construction and construction-related expenses in connection with the construction of our sixth generation ultra-deepwater drillships, the Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos, which were delivered to us on January 3, 2011, March 30, 2011, July 28, 2011 and September 30, 2011, respectively. The total cost of construction and construction related expenses for the Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos amounted to approximately $755.7 million, $756.9 million, $791.8 million and $784.4 million, respectively. Construction related expenses include equipment purchases, commissioning, supervision and commissions to related parties, excluding financing costs.

During the year ended December 31, 2012 and during 2013 to date, our principal capital expenditures related to construction expenses in connection with the construction of the Ocean Rig Mylos, the Ocean Rig Skyros, the Ocean Rig Athena and the Ocean Rig Apollo, our seventh generation drillships under construction, scheduled to be delivered in July 2013, October 2013, November 2013 and January 2015, respectively. For more information on our seventh generation drillships, please see "—B. Business Overview— Newbuilding Drillships and Options to Purchase Newbuilding Drillships." As of December 31, 2012, we had paid an aggregate of $879.4 million to Samsung in connection with our four seventh generation drillships, which we financed with cash from operations. The remaining total construction payments for these drillships, excluding financing costs, amounted to approximately $1.6 billion in the aggregate as of December 31, 2012. We plan to finance these remaining payments, which are due upon delivery of the drillships, with new debt or equity financing, which we have not yet secured in full. In February 2013, we entered into a $1.35 billion senior secured term loan facility to partially finance the construction costs of the Ocean Rig Mylos, the Ocean Rig Skyros and the Ocean Rig Athena. We cannot be certain that we will be able to obtain the additional financing we need to complete the acquisition of our seventh generation drillships on acceptable terms or at all.

B. Business Overview

We are an international offshore drilling contractor providing oilfield services for offshore oil and gas exploration, development and production drilling and specializing in the ultra-deepwater and harsh-environment segment of the offshore drilling industry. We seek to utilize our high-specification drilling units to the maximum extent of their technical capability and we believe that we have earned a reputation for operating performance excellence, customer service and safety.

We, through our wholly-owned subsidiaries, currently own and operate two modern, fifth generation ultra-deepwater semisubmersible offshore drilling rigs, the Leiv Eiriksson and the Eirik Raude, and four sixth generation advanced capability ultra-deepwater drillships, the Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos, delivered in January 2011, March 2011, July 2011 and September 2011, respectively, by Samsung. The Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos are "sister-ships" constructed by Samsung to the same high-quality vessel design and specifications and are capable of drilling in water depths of 10,000 feet. We believe that owning and operating "sister-ships" helps us maintain our cost efficient operations on a global basis through the shared inventory and use of spare parts and the ability of our offshore maritime crews to work seamlessly across all of our drillships.

We have additional newbuilding contracts with Samsung for the construction of the Ocean Rig Mylos, the Ocean Rig Skyros, the Ocean Rig Athena and the Ocean Rig Apollo, our four seventh generation drillships scheduled for delivery in July 2013, October 2013, November 2013 and January 2015, respectively, which will be "sister ships" to our operating drillships. The design of our seventh generation drillships reflects additional enhancements that, with the purchase of additional equipment, will enable the drillships to drill in water depths of 12,000 feet. We currently have a team overseeing the construction of the newbuilding drillships at Samsung to help ensure that those drillships are built on time, to our exact vessel specifications and on budget, as was the case for our operating drillships. The remaining total construction payments for these drillships, excluding financing costs, amounted to approximately $1.6 billion in the aggregate as of December 31, 2012. To date, the construction of these four newbuiding drillships is on budget and no time delays on delivery are expected.

We employ our drilling units primarily on a dayrate basis for periods of between two months and three years to drill wells for our customers, typically major oil companies, integrated oil and gas companies, state-owned national oil companies and independent oil and gas companies.

We also have options with Samsung for the construction of up to two additional ultra-deepwater drillships, which would also be sister-ships to our seventh generation drillships under construction. The deadline for exercising these options is March 31, 2013, with the option drillships, if exercised, being delivered on the earliest available delivery dates based on the production schedule, as determined by Samsung in its reasonable discretion, and at a price to be mutually agreed at the time of the option declaration.

We believe that our operating drillships, the Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos, as well as our four seventh generation drillships under construction, are among the most technologically advanced drillships in the world. The S10000E design, used for our operating drillships, was originally introduced in 1998 and has been widely accepted by customers. Including our operating drillships, a total of 56 drillships have been ordered using this base design, of which 35 have been delivered, as of February 2013, including the Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos. Among other technological enhancements, our drillships are equipped with dual activity drilling technology, which involves two drilling systems using a single derrick that permits two drilling-related operations to take place simultaneously. We estimate this technology saves between 15% and 40% in drilling time, depending on the well parameters. Each of our operating drillships is capable of drilling 40,000 feet at water depths of 10,000 feet and our seventh generation drillships will have the capacity to drill 40,000 feet at water depths of 12,000 feet.

Our Fleet

Set forth below is summary information concerning our offshore drilling units as of the date of this annual report.

Water

Depth to

the

Wellhead

(ft)

Drilling

Depth to

the

Oil Field

(ft)

Year Built or

Scheduled

Delivery/

Generation

Maximum

Dayrate

Drilling

Location

Drilling Unit

Customer

Expected Contract Term(1)

Operating Drilling Rigs

Leiv Eiriksson

2001/5th

7,500

30,000

Rig Management Norway AS(2)

Q1 2013–

Q1 2016

$545,000

Norwegian

Continental

Shelf

Eirik Raude

2002/5th

10,000

30,000

ExxonMobil Exploration and Production Ireland (Offshore) Limited

Q1 2013 – Q3 2013 (3)

$595,000

Ireland

Lukoil Overseas Sierra-Leone B.V.

Q4 2013 – Q4 2014

$575,000

West Africa

Operating Drillships

Ocean Rig Corcovado

2011/6th

10,000

40,000

Petróleo Brasileiro S.A.

Q2 2012–

Q2 2015

$446,000(4)

Brazil

Ocean Rig Olympia

2011/6th

10,000

40,000

Total E&P Angola

Q3 2012–

Q3 2015

$584,450(5)

West Africa

Ocean Rig Poseidon

2011/6th

10,000

40,000

Petrobras Tanzania Limited

Q3 2011–

Q1 2013

$632,000(6)

Tanzania and

West Africa

ENI Angola S.p.A.

Q2 2013–

Q2 2016

$690,300(7)

Angola

Ocean Rig Mykonos

2011/6th

10,000

40,000

Petróleo Brasileiro S.A.

Q1 2012–

Q1 2015

$441,000(4)

Brazil

Ocean Rig Mylos

Q3 2013/7th

12,000

40,000

Repsol Sinopec Brasil S.A.

Q3 2013–

Q3 2016

$624,842(8)

Brazil

Ocean Rig Skyros

Q4 2013/7th

12,000

40,000

Ocean Rig Athena

Q4 2013/7th

12,000

40,000

ConocoPhillips Angola 36 & 37 Ltd

Q4 2013–

Q1 2017

$648,096(9)

Angola

Ocean Rig Apollo

Q1 2015/7th

12,000

40,000

Major Oil Company(10)

West Africa

Optional Newbuilding Drillships (11)

NB Option #1

7th

12,000

40,000

NB Option #2

7th

12,000

40,000

_____________________

(1) Not including the exercise of any applicable options to extend the term of the contract.

(2) Rig Management Norway is the coordinator for the consortium under the contract. The contract has a minimum duration of 1,070 days and includes three options of up to six wells each that must be exercised prior to the expiration of the firm contract period in the first quarter of 2016.

(3) We commenced this contract in March 2013, earlier than originally scheduled, following the cancellation of our contract with European Hydrocarbons Limited effective on March 3, 2013.

(4) Approximately 20% of the maximum dayrates are service fees paid to us in Brazilian Real (R$). The maximum dayrate disclosed in this table is based on the March 1, 2013 exchange rate of R$1.97:$1.00.

(5) Total E&P Angola has the option to extend the term of the contract for two additional one-year periods at the dayrate of $584,450, adjusted annually for inflation, with the first option exercisable within one year from the commencement date under the drilling contract, and the second option exercisable within one year after the date of exercise of the first option.

(6) We assigned this contract to Petrobras Oil & Gas B.V. for the performance of drilling operations with respect to one well offshore Namibia. The maximum dayrate under the contract during the assignment period, which commenced on July 27, 2012 and terminated on September 26, 2012, was $590,882, comprised of the operating dayrate during the period of $547,854 plus the maximum performance bonus during the period. Following the assignment period, the maximum dayrate increased to $632,000, comprised of the operating dayrate of $586,000 plus the maximum performance bonus under the contract.

(7) The maximum dayrate of $690,300 is the average maximum dayrate applicable during the initial three-year term of the contract. Under the contract, the initial maximum dayrate of $670,000 will increase annually at a rate of 3%, beginning twelve months after the commencement date, during the term of the contract. ENI has the option to extend the term of the contract by two optional periods of one-year each. In the event ENI exercises the option for both optional years on or before the date the contract is commenced, the maximum dayrate will decrease by $15,000 per day and, in the event ENI exercises the option for both optional years within the first year of the date the contract is commenced, the maximum dayrate will decrease by $10,000 per day.

(8) To commence upon delivery of the drillship from the shipyard or to the drilling location and the provisional acceptance of the drillship by Repsol at an average maximum dayrate of approximately $624,842 over the term of the contract. A portion of the maximum dayrate is service fees paid to us in Brazilian Real (R$). The average maximum dayrate disclosed in this table is based on the March 1, 2013 exchange rate of R$1.97:$1.00. Under the contract, Repsol has options to extend the contract for up to two years beyond the initial three-year contract period.

(9) The maximum dayrate of $648,096 is the average maximum dayrate applicable during the initial three-year term of the contract. Under the contract, the initial maximum dayrate of $633,500 is subject to a fixed annual escalation of approximately 2% during the contract period. Under the contract, ConocoPhillips has the option to extend the initial contract period by up to two years.

(10) We have received a letter of award from a major oil company for a three-year drilling contract, to commence upon delivery of the drillship from the shipyard. The contract is subject to final documentation and customary conditions.

(11) Each of the options currently expires on March 31, 2013.

Newbuilding Drillships and Options to Purchase Newbuilding Drillships

We have entered into shipbuilding contracts for the Ocean Rig Mylos, the Ocean Rig Skyros, the Ocean Rig Athena and the Ocean Rig Apollo, our seventh generation drillships with deliveries scheduled in July 2013, October 2013, November 2013 and January 2015, respectively, in connection with which we had made total payments of $879.4 million to Samsung, as of December 31, 2012. The total project cost per drillship, excluding financing costs, ranges between $668.0 million and $678.0 million.

We also have options with Samsung for the construction of up to two additional ultra-deepwater drillships, which would be "sister-ships" to our seventh generation drillships. On September 3, 2012, we entered into an addendum to our option contract with Samsung to extend the deadline for exercising these options from October 4, 2012 to March 31, 2013, with the vessels being delivered on the earliest available delivery dates based on the production schedule, as determined by Samsung in its reasonable discretion, and at a price to be mutually agreed at the time of the option declaration.

Employment of Our Fleet

Employment of Our Drilling Rigs

The Leiv Eiriksson is currently on drydock at Westcon, a Norwegian shipyard, to complete scheduled equipment and winterization upgrades relating to a drilling contract the rig is scheduled to commence with a consortium coordinated by Rig Management Norway, or Rig Management, for the drilling of 15 wells on the Norwegian Continental Shelf at a maximum dayrate of $545,000. We also expect to receive approximately $83.0 million under the contract to cover mobilization and fuel costs as well as the cost of equipment upgrades to operate in the Norwegian Continental Shelf. The contract has a minimum duration of 1,070 days and includes three options of up to six wells each that must be exercised prior to the expiration of the firm contract period in the first quarter of 2016. Following the completion of the drydock discussed above, the rig is scheduled to undergo acceptance testing at the drilling location in Norway and is expected to commence drilling operations under the contract on or prior to April 15, 2013.

Following the completion of its 10-year class survey in December 2012, the Eirik Raude commenced a drilling contract with European Hydrocarbons for the drilling of two wells offshore West Africa at a maximum dayrate of $718,750, which included the operating dayrate of $625,000, plus the maximum performance bonus available under the contract. We also received a mobilization fee under the contract of $15.0 million plus the cost of fuel consumed during the mobilization period. On March 3, 2013, our customer unilaterally cancelled the contract. We are entitled to an early termination payment of approximately $13.7 million under the contract. As a result of the cancellation, we will not receive approximately $14.1 million in estimated contract revenues, after giving effect to the early termination payment.

Following the cancellation of our contract with European Hydrocarbons, the Eirik Raude commenced a one-well drilling contract with an estimated duration of up to six months with ExxonMobil Exploration and Production Ireland (Offshore) Limited, or ExxonMobil, for drilling offshore Ireland at a maximum dayrate of $595,000. In addition, we are entitled to receive a mobilization fee of $589,050 per day during the mobilization period plus a $5.0 million start-up fee and reimbursement for the cost of fuel and a demobilization fee of $589,050 per day during the demobilization period, plus reimbursement for the cost of fuel, unless the parties mutually agree on lump-sum mobilization and demobilization fees. The Eirik Raude commenced the contract in the first quarter of 2013, earlier than originally scheduled, due to the early termination of the drilling contract with European Hydrocarbons.

Following the completion of the contract with ExxonMobil discussed above, the Eirik Raude is scheduled to commence a four well drilling contract with Lukoil Overseas Sierra-Leone B.V., or Lukoil, an with estimated duration of approximately 12 months. We are entitled to a maximum dayrate of $575,000 under the contract, plus a mobilization fee of $6.0 million, plus the cost of fuel. We are also entitled to demobilization fees of between $1.0 million and $5.0 million, plus fuel costs, depending on the location of the rig, provided the rig is not hired by other customers in direct continuation of the contract. Under the contract, Lukoil has the option to extend the term of the contract by up to two additional wells. The contract is scheduled to commence in the second half of 2013.

Employment of Our Drillships

The Ocean Rig Corcovado is currently employed under a three-year drilling contract, plus a mobilization period with Petrobras Brazil for drilling operations offshore Brazil at a maximum dayrate of $446,000 (including service fees of $78,000 per day, based on the contracted rate in Real per day and the March 1, 2013 exchange rate of R$1.97:USD $1.00), plus a mobilization fee of $30.0 million. The contract is scheduled to be completed in the second quarter of 2015.

The Ocean Rig Olympia commenced a three-year drilling contract with Total E&P Angola in July 2012 for drilling operations offshore West Africa at a maximum dayrate of $584,450, plus mobilization and demobilization fees of $9.0 million and $3.5 million, respectively, plus the cost of fuel. Under the contract, Total E&P Angola has the option to extend the term of the contract for two additional one-year periods at the dayrate specified above, adjusted annually for inflation, with the first option exercisable within one year from the commencement date under the drilling contract, and the second option exercisable within one year after the date of exercise of the first option.

The Ocean Rig Poseidon commenced a drilling contract with Petrobras Tanzania, a company related to Petrobras Oil & Gas B.V., or Petrobras Oil & Gas, on July 29, 2011, for drilling operations in Tanzania and West Africa for a period of 544 days, plus a 60-day mobilization period, at a maximum dayrate of $632,000, inclusive of a bonus of up to $46,000. In addition, we are entitled to receive a separate dayrate of $422,500 for up to 60 days during relocation and a mobilization dayrate of $317,000, plus the cost of fuel. On July 6, 2012, we entered into an assignment and novation agreement with Petrobras Tanzania and Petrobras Oil & Gas, pursuant to which the contract has been assigned to Petrobras Oil & Gas for the performance of drilling operations with respect to one well offshore Namibia. During the assignment period, which commenced on July 27, 2012 and terminated on September 26, 2012, the maximum dayrate under the contract decreased to $590,882, inclusive of a performance bonus of up to $43,028. The contract is scheduled to expire in April 2013.

Following the expiration of its contract with Petrobras Tanzania, the Ocean Rig Poseidon is scheduled to commence a three-year drilling contract with ENI Angola S.p.A., or ENI, in the second quarter of 2013 for drilling operations offshore Angola at a maximum dayrate of $690,300, which is the average maximum dayrate applicable during the initial three-year term of the contract. During the term of the contract, the initial maximum dayrate of $670,000 will increase annual at a rate of 3%, beginning twelve months after the commencement date. The contract also includes a mobilization rate of $656,600 per day, plus reimbursement for the cost of fuel, and a demobilization fee of $5.0 million. Under the contract, ENI has the option to extend the term of the contract by two optional periods of one year each. In the event ENI exercises the option for both optional years on or before the date the contract is commenced, the maximum dayrate will decrease by $15,000 per day and, in the event ENI exercises the option for both optional years within the first year of the date the contract is commenced, the maximum dayrate will decrease by $10,000 per day.

The Ocean Rig Mykonos commenced a three-year drilling contract, plus a mobilization period, with Petrobras Brazil, on September 30, 2011, for drilling operations offshore Brazil at a maximum dayrate of $441,000 (including service fees of $77,000 per day, based on the contracted rate in Real and the March 1, 2013 exchange rate of R$1.97: $1.00), plus a mobilization fee of $30.0 million. The contract is scheduled to expire in February 2015.

In addition, we have entered into a three-year drilling contract with Repsol for drilling operations offshore Brazil for the Ocean Rig Mylos, our seventh generation drillship scheduled for delivery in July 2013, which is expected to commence following delivery of the drillship from the shipyard or to the drilling location and the provisional acceptance of the drillship by Repsol. We are entitled to receive an average maximum dayrate of $624,842 over the term of the contract. A portion of the average maximum dayrate is service fees payable in Brazilian Real and such dayrate is based on the March 1, 2013 exchange rate of R$1.97:$1.00. Under the contract, Repsol has options to extend the contract for up to two years beyond the initial three-year contract period.

Further, we have entered into a three-year contract with ConocoPhillips Angola 36 and 37 Ltd, or ConocoPhillips, for drilling operations offshore Angola for the Ocean Rig Athena, our seventh generation drillship scheduled for delivery in November 2013, which is expected to commence following the delivery of the drillship from the shipyard or to the drilling location. We are entitled to a maximum dayrate of approximately $648,096, which is the average maximum dayrate applicable during the initial three-year term of the contract, plus a lump-sum mobilization fee of $35,227,500, exclusive of fuel costs. Under the contract, the initial maximum dayrate of $633,500 is subject to a fixed annual escalation of approximately 2% during the contract period. In addition, Conoco Phillips has the option to extend the duration of the contract for two years.

We have also received a letter of award from a major oil company for a three-year drilling contract offshore West Africa with an estimated backlog of approximately $680.0 million, including mobilization, for the Ocean Rig Apollo, our seventh generation drillship scheduled for delivery in January 2015. The contract is scheduled to commence in the first quarter of 2015. The customer has the option to extend the term of the contract for four periods of six months each, with the first option exercisable not less than one year before completion date. We have the option to elect the Ocean Rig Apollo or a similar vessel, to drill under this contract. The contract is subject to definitive documentation and customary conditions.

The total contracted backlog under our drilling contracts for our drilling units, including our rigs, as of March 4, 2013, was $4.4 billion. We calculate our contract backlog by multiplying the contractual dayrate under all of our employment contracts for which we have firm commitments as of March 4, 2013, by the minimum expected number of days committed under such contracts (excluding any options to extend), assuming full utilization. There can be no assurance that the counterparties to such contracts will fulfill their obligations under the contracts. See the section of this annual report entitled "Item 3. Key Information—Risk Factors—Risks Relating to Our Company—Our future contracted revenue for our fleet of drilling units may not be ultimately realized."

Unless otherwise stated, all references to maximum dayrates included in this annual report are exclusive of any applicable annual contract revenue adjustments, which generally result in the escalation of the dayrates payable under the drilling contracts.

Management of Our Fleet

Our wholly owned subsidiary, Ocean Rig AS, provides supervisory management services including onshore management, to our operating drilling rigs and drillships pursuant to separate management agreements entered into with each of the drilling unit-owning subsidiaries. Ocean Rig AS also provides supervisory management services for our seventh generation drillships under construction.

Under the terms of these management agreements, Ocean Rig AS, through its affiliates in Stavanger, Norway, Aberdeen, United Kingdom and Houston, Texas, is responsible for, among other things, (i) assisting in construction contract technical negotiations, (ii) securing contracts for the future employment of the drilling units, and (iii) providing commercial, technical and operational management for the drillships.

In addition, we have engaged Cardiff Drilling, a company controlled by our Chairman, President and Chief Executive Officer, Mr. George Economou, to provide us with consulting and other services with respect to the arrangement of employment for, and relating to the purchase and sale of, our drilling units. See "Item 7. Major Shareholders and Related Party Transactions—B. Related Party Transactions—Global Services Agreements."

The Offshore Drilling Industry

In recent years, the international drilling market has seen an increasing trend towards deep and ultra-deepwater oil and gas exploration. As shallow water resources mature, deep and ultra-deepwater regions are expected to play an increasing role in offshore oil and gas exploration and production. According to industry sources, the industry-wide global ultra-deepwater market has seen rapid development over the last six years, with dayrates increasing from approximately $180,000 in 2004 to above $600,000 in 2008. As of February 2013, the market level is approximately $600,000. The ultra-deepwater market rig utilization rate has been stable, above 80% since 2000 and above 97% since 2006. The operating units capable of drilling in ultra-deepwater depths of greater than 7,500 feet consist mainly of fifth and sixth generation units, and also include certain older upgraded units. The in-service fleet as of February 2013 totaled 121 units, and is expected to grow to 206 units upon the scheduled delivery of the current newbuild orderbook by the end of 2020. Historically, an increase in supply has caused a decline in utilization and dayrates until drilling units are absorbed into the market. Accordingly, dayrates have been very cyclical. We believe that the largest undiscovered offshore reserves are mostly located in ultra-deepwater fields and primarily located in the "golden triangle" between West Africa, Brazil and the Gulf of Mexico, as well as in East Africa, Australia and Southeast Asia. The location of these large offshore reserves has resulted in more than 90% of the floating drilling unit, or floater, orderbook being represented by ultra-deepwater units. Furthermore, due to increased focus on technically challenging operations and the inherent risk of developing offshore fields in ultra-deepwater, particularly in light of the Deepwater Horizon accident in the Gulf of Mexico, in which we were not involved, oil companies have already begun to show a preference for modern units more capable of drilling in these challenging environments.

Markets

Our operations are geographically dispersed in oil and gas exploration and development areas worldwide. Although the cost of moving a rig and the availability of rig-moving vessels may cause the balance between supply and demand to vary between regions, significant variations do not tend to exist long-term because of rig mobility. Consequently, we operate in a single, global offshore drilling market. Because our drilling rigs are mobile assets and are able to be moved according to prevailing market conditions, we cannot predict the percentage of our revenues that will be derived from particular geographic or political areas in future periods.

In recent years, there has been increased emphasis by oil companies to expand their proven reserves and thus focus on exploring for hydrocarbons in deeper waters. This deepwater focus is due, in part, to technological developments that have made such exploration more feasible and cost-effective. Therefore, water-depth capability is a key component in determining rig suitability for a particular drilling project. Another distinguishing feature in some drilling market sectors is a rig's ability to operate in harsh environments, including extreme marine and climatic conditions and temperatures.

Our drilling units service the ultra-deepwater sector of the offshore drilling market. Although the term "deepwater" as used in the drilling industry to denote a particular sector of the market can vary and continues to evolve with technological improvements, we generally view the deepwater market sector as that which begins in water depths of approximately 4,500 feet and extends to the maximum water depths in which seventh generation rigs are capable of drilling, which is currently approximately 12,000 feet.

Our Customers

Our customers are generally major oil companies, integrated oil and gas companies, state-owned national oil companies and independent oil and gas companies. We, together with our predecessor, Ocean Rig ASA, have an established history with 151 wells drilled in 18 countries for 29 different customers as of March 2013.

For the years ended December 31, 2010, 2011 and 2012, the following customers, which represent all of our customers for the years indicated, accounted for more than 10% of our consolidated annual revenues:

Customer	Year ended December 31, 2010			Year ended December 31, 2011			Year ended December 31, 2012
Customer A		57	%		36	%		-
Customer B		43	%		18	%		49	%
Customer C		-			-			18	%
Customer D		-			33	%		12	%
Customer E		-			13	%		-

Contract Drilling Services

Our contracts to provide offshore drilling services and drilling units are individually negotiated and vary in their terms and provisions. We generally obtain our contracts through competitive bidding against other contractors. The contracts for our drilling units typically provide for compensation on a "dayrate" basis under which we are paid a fixed amount for each day that the vessel is operating under a contract at full efficiency, with higher rates while the drilling unit is operating and lower rates for periods of mobilization or when drilling operations are interrupted or restricted by equipment breakdowns, adverse environmental conditions or other conditions beyond our control. Under most dayrate contracts, we pay the operating expenses of the rig or drillship, including planned rig maintenance, crew wages, insurance and the cost of supplies.

A dayrate drilling contract generally extends over a period of time covering either the drilling of a single well or group of wells or covering a stated term, as do the current contracts under which our drilling units are employed. Currently, there is no spot market for offshore drilling units. The length of shorter-term contracts is typically from 60 to 365 days and the longer-term contracts are typically from two to five years. The contract term in some instances may be extended by the client exercising options for the drilling of additional wells or for an additional term. Our contracts also typically include a provision that allows the client to extend the contract to finish drilling a well-in-progress.

From time to time, contracts with customers in the offshore drilling industry may contain terms whereby the customer has an option to cancel upon payment of an early termination payment, but where such payments may not fully compensate for the loss of the contract. Contracts also customarily provide for either automatic termination or termination at the option of the customer typically without the payment of any termination fee, under various circumstances such as major nonperformance, in the event of substantial downtime or impaired performance caused by equipment or operational issues, or sustained periods of downtime due to force majeure events. Many of these events are beyond our control.

We expect that provisions of future contracts will be similar to those in our current contracts for our drilling units. See "—Employment of our Fleet."

Competition

The offshore contract drilling industry is competitive with numerous industry participants, few of which at the present time have a dominant market share. The drilling industry has experienced consolidation in recent years and may experience additional consolidation, which could create additional large competitors. Many of our competitors have significantly greater financial and other resources, including more drilling units, than us. We compete with offshore drilling contractors that, as of February 2013, together have approximately 195 deepwater and ultra-deepwater drilling units worldwide, defined as units with water depth capacity of 3,000 feet or more.

The offshore contract drilling industry is influenced by a number of factors, including global demand for oil and natural gas, current and anticipated prices of oil and natural gas, expenditures by oil and gas companies for exploration and development of oil and natural gas and the availability of drilling rigs. In addition, mergers among oil and natural gas exploration and production companies have reduced, and may from time to time reduce, the number of available customers.

Drilling contracts are traditionally awarded on a competitive bid basis. Intense price competition is often the primary factor in determining which qualified contractor is awarded a contract. Customers may also consider unit availability, location and suitability, a drilling contractor's operational and safety performance record, and condition and suitability of equipment. We believe that we compete favorably with respect to these factors.

We compete on a worldwide basis, but competition may vary significantly by region at any particular time. Competition for offshore units generally takes place on a global basis, as these units are highly mobile and may be moved from one region to another, at a cost that may be substantial. Competing contractors are able to adjust localized supply and demand imbalances by moving units from areas of low utilization and dayrates to areas of greater activity and relatively higher dayrates. Significant new unit construction and upgrades of existing drilling units could also intensify price competition.

Seasonality

In general, seasonal factors do not have a significant direct effect on our business as most of our drilling units are contracted for periods of at least 12 months. However, our drilling units may perform drilling operations in certain parts of the world where weather conditions during parts of the year could adversely impact the operational utilization of our drilling units and our ability to relocate units between drilling locations, and as such, limit contract opportunities in the short term. Such adverse weather could include the hurricane season for our operations in the Gulf of Mexico, the winter season in offshore Norway, and the monsoon season in Southeast Asia.

Environmental and Other Regulations

Our offshore drilling operations include activities that are subject to numerous international, federal, state and local laws and regulations, including the International Convention for the Prevention of Pollution from Ships, or MARPOL, the International Convention on Civil Liability for Oil Pollution Damage of 1969, generally referred to as CLC, the International Convention on Civil Liability for Bunker Oil Pollution Damage, or Bunker Convention, the International Convention for the Safety of Life at Sea of 1974, or SOLAS, the International Safety Management Code for the Safe Operation of Ships and for Pollution Prevention, or ISM Code, the International Convention for the Control and Management of Ships' Ballast Water and Sediments in February 2004, or the BWM Convention, the U.S. Oil Pollution Act of 1990, or OPA, the Comprehensive Environmental Response, Compensation and Liability Act, or CERCLA, the U.S. Clean Water Act, the U.S. Clean Air Act, the U.S. Outer Continental Shelf Lands Act, the U.S. Maritime Transportation Security Act of 2002, or the MTSA, European Union regulations, and Brazil's National Environmental Policy Law (6938/81), Environmental Crimes Law (9605/98) and Law (9966/2000) relating to pollution in Brazilian waters. These laws govern the discharge of materials into the environment or otherwise relate to environmental protection. In certain circumstances, these laws may impose strict liability, rendering us liable for environmental and natural resource damages without regard to negligence or fault on our part.

For example, the United Nations' International Maritime Organization, or IMO, has adopted MARPOL. Annex VI to regulate harmful air emissions from ships, which include rigs and drillships. Amendments to the Annex VI regulations which entered into force on July 1, 2010, require a progressive reduction of sulfur oxide levels in heavy bunker fuels and create more stringent nitrogen oxide emissions standards for marine engines in the future. Effective August 1, 2012, certain coastal areas of North America were designated ECAs, as will (effective January 1, 2014), the United States Caribbean Sea. We may incur costs to comply with these revised standards. Rigs and drillships must comply with MARPOL limits on emissions of sulfur oxide, nitrogen oxide, chlorofluorocarbons and other air pollutants, except that the MARPOL limits do not apply to emissions that are directly related to drilling, production, or processing activities. We believe that all of our drilling units are currently compliant in all material respects with these regulations.

Our drilling units are subject not only to MARPOL regulation of air emissions, but also to the Bunker Convention's strict liability for pollution damage caused by discharges of bunker fuel in jurisdictional waters of ratifying states.

Furthermore, any drillships that we may operate in United States waters, including the U.S. territorial sea and the 200 nautical mile exclusive economic zone around the United States, would have to comply with OPA and CERCLA requirements, among others, that impose liability (unless the spill results solely from the act or omission of a third party, an act of God or an act of war) for all containment and clean-up costs and other damages arising from discharges of oil or other hazardous substances, other than discharges related to drilling.

The U.S. BSEE periodically issues guidelines for rig fitness requirements in the Gulf of Mexico and may take other steps that could increase the cost of operations or reduce the area of operations for our units, thus reducing their marketability. Implementation of BSEE guidelines or regulations may subject us to increased costs or limit the operational capabilities of our units and could materially and adversely affect our operations and financial condition.

Numerous governmental agencies issue regulations to implement and enforce the laws of the applicable jurisdiction, which often involve lengthy permitting procedures, impose difficult and costly compliance measures, particularly in ecologically sensitive areas, and subject operators to substantial injunctive relief and administrative, civil and criminal penalties for failure to comply. Changes in environmental laws and regulations occur frequently, and any changes that result in more stringent and costly compliance or limit contract drilling opportunities, including changes in response to a serious marine incident that results in significant oil pollution or otherwise causes significant adverse environmental impact, such as the April 2010 Deepwater Horizon oil spill in the Gulf of Mexico, in which we were not involved, could adversely affect our financial results. While we believe that we are in substantial compliance with the current laws and regulations, there is no assurance that compliance can be maintained in the future.

In addition to the MARPOL, OPA, and CERCLA requirements described above, our international operations are subject to various other international conventions and laws and regulations in countries in which we operate, including laws and regulations relating to the importation of and operation of drilling units and equipment, currency conversions and repatriation, oil and gas exploration and development, environmental protection, taxation of offshore earnings and earnings of expatriate personnel, the use of local employees and suppliers by foreign contractors and duties on the importation and exportation of drilling units and other equipment. New environmental or safety laws and regulations could be enacted, which could adversely affect our ability to operate in certain jurisdictions. Governments in some countries have become increasingly active in regulating and controlling the ownership of concessions and companies holding concessions, the exploration for oil and gas and other aspects of the oil and gas industries in their countries. In some areas of the world, this governmental activity has adversely affected the amount of exploration and development work done by major oil and gas companies and may continue to do so. Operations in less developed countries can be subject to legal systems that are not as mature or predictable as those in more developed countries, which can lead to greater uncertainty in legal matters and proceedings.

Implementation of new environmental laws or regulations that may apply to ultra-deepwater drilling units may subject us to increased costs or limit the operational capabilities of our drilling units and could materially and adversely affect our operations and financial condition.

Insurance for Our Offshore Drilling Units

We maintain insurance for our drilling units in accordance with industry standards. Our insurance is intended to cover normal risks in our current operations, including insurance against property damage, loss of hire, war risk and third-party liability, including pollution liability. The insurance coverage is established according to the Norwegian Marine Insurance Plan of 1996, version 2010, but excluding collision liabilities which are covered by the Protection and Indemnity insurance. We have obtained insurance for the full assessed market value of our drilling units, as assessed by rig brokers. Our insurance provides for premium adjustments based on claims and is subject to deductibles and aggregate recovery limits. In the case of pollution liabilities, our deductible is $10,000 per event and in the case of other hull and machinery claims, our deductible is $1.5 million per event. Our insurance coverage may not protect fully against losses resulting from a required cessation of drilling unit operations for environmental or other reasons. We also have loss of hire insurance cover for approximately one year which becomes effective after 45 days. This loss of hire insurance is recoverable only if there is physical damage to the rig or equipment which is caused by a peril against which we are insured. The principal risks which may not be insurable are various environmental liabilities and liabilities resulting from reservoir damage caused by our negligence. In addition, insurance may not be available to us at all or on terms acceptable to us, and there is no guarantee that even if we are insured, our policy will be adequate to cover our loss or liability in all cases. We plan to maintain insurance for our seventh generation drillships upon their delivery to us in accordance with the Norwegian Marine Insurance Plan of 1996, version 2010. This insurance would also be intended to cover normal risks in our current operations, including insurance against property damage, loss of hire and war risks. Third-party liability, including pollution liability and collision liability, is covered under our protection and indemnity insurance.

Permits and Authorizations

We are required by various governmental and quasi-governmental agencies to obtain certain permits, licenses and certificates with respect to our drilling units. The kinds of permits, licenses and certificates required depend upon several factors, including the waters in which a drilling unit operates, the nationality of a drilling unit's crew and the age of a drilling unit. We have been able to obtain all permits, licenses and certificates currently required to permit our drilling units to operate. Additional laws and regulations, environmental or otherwise, may be adopted which could limit our ability to do business or increase the cost of us doing business.

C. Organizational Structure

For a full list of our subsidiaries, please see Exhibit 8.1 to this annual report. All of the subsidiaries are, directly or indirectly, wholly-owned by Ocean Rig UDW Inc., except for Ocean Rig Deepwater Drilling Ltd., of which all but one of the issued and outstanding shares is owned by Ocean Rig UDW Inc. and the remaining outstanding share is owned by a director of the company, and Ocean Rig Angola Ltd., which is 51% owned by Angolan shareholders and 49% owned by Ocean Rig UDW Inc.

As of March 20, 2013, DryShips (NASDAQGS: DRYS) owned approximately 59.4% of our total outstanding common shares.

D. Property, Plants and Equipment

We do not own any real property. We maintain our principal executive offices in Nicosia, Cyprus and certain of our subsidiaries lease office space from unaffiliated third parties for offices in Stavanger, Norway, Houston, Texas, Aberdeen, United Kingdom, Accra, Ghana, Rio de Janeiro, Brazil, Dar es Salam, Tanzania, Abidjan, Ivory Coast and Geoje, South Korea. Our interests in the drilling units in our fleet are our only material properties. See "—B. Business Overview—Our Fleet" in this section.

Item 4A. Unresolved Staff Comments

Not applicable.

Item 5. Operating and Financial Review and Prospects

The following is a discussion of financial condition and results of operations of Ocean Rig UDW Inc. and its wholly-owned subsidiaries for the years referenced below. You should read this section together with the historical consolidated financial statements, including the notes to those historical consolidated financial statements, for those same years included in this annual report. All of the consolidated financial statements included herein have been prepared in accordance with U.S. GAAP. See "—Results of operations."

This discussion includes forward-looking statements which, although based on assumptions that we consider reasonable, are subject to risks and uncertainties, which could cause actual events or conditions to differ materially from those currently anticipated and expressed or implied by such forward-looking statements. For a discussion of some of those risks and uncertainties, please see the section entitled "Forward-Looking Statements" at the beginning of this annual report and "Item. 3 Key Information—D. Risk Factors."

A. Operating Results

Overview

We are an international offshore drilling contractor providing oilfield services and drilling vessels for offshore oil and gas exploration, development and production drilling, and specializing in the ultra-deepwater and harsh-environment segment of the offshore drilling industry. We, through our wholly-owned subsidiaries, currently own and operate two modern, fifth generation ultra-deepwater semi-submersible offshore drilling rigs, the Leiv Eiriksson and the Eirik Raude, and four sixth generation advanced capability ultra-deepwater drillships, the Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon, and the Ocean Rig Mykonos, which were delivered to us on January 3, 2011, March 30, 2011, July 28, 2011 and September 30, 2011, respectively. We have newbuilding contracts with Samsung for the construction of the four seventh generation drillships, the Ocean Rig Mylos, the Ocean Rig Skyros, the Ocean Rig Athena and the Ocean Rig Apollo. These newbuilding drillships are currently scheduled for delivery in July 2013, October 2013, November 2013 and January 2015, respectively.

History of Our Company

We were formed under the laws of the Republic of the Marshall Islands on December 10, 2007, under the name Primelead Shareholders Inc. and as a wholly-owned subsidiary of DryShips.

Our predecessor, Ocean Rig ASA, was incorporated on September 26, 1996 under the laws of Norway and contracted for the construction of our two operating drilling rigs, the Leiv Eiriksson and the Eirik Raude. The shares of Ocean Rig ASA traded on the Oslo Stock Exchange from January 1997 to July 2008.

In December 2007, Primelead Limited, our wholly-owned subsidiary, acquired approximately 30.4% of the outstanding capital stock of Ocean Rig ASA from Cardiff Marine Inc., or Cardiff Marine, a company controlled by the Chairman, President and Chief Executive Officer of DryShips and us. After acquiring more than 33% of Ocean Rig ASA's outstanding shares through a series of transactions through April 2008, we launched a mandatory offer for the remaining shares of Ocean Rig ASA at a price of NOK45 per share, or $8.89 per share, as required by Norwegian law. We gained control over Ocean Rig ASA on May 14, 2008. As of July 10, 2008, we held 100% of the shares of Ocean Rig ASA, or 163.6 million shares, which we acquired at a total cost of $1.4 billion.

With respect to the acquisition of Ocean Rig ASA, discussed above, DryShips purchased 4.4% of the share capital of Ocean Rig ASA from companies affiliated with our Chairman, President and Chief Executive Officer. In March 2009, DryShips contributed to us all of its equity interests in the newbuilding vessel-owning companies of the Ocean Rig Poseidon and Ocean Rig Mykonos. In May 2009, we acquired the equity interests of Drillships Holdings Inc., the owner of the Ocean Rig Corcovado and the Ocean Rig Olympia, from third parties and entities affiliated with our Chairman, President and Chief Executive Officer and, in exchange, we issued to the sellers common shares equal to 25% of our total issued and outstanding common shares as of May 15, 2009. In connection with the acquisition the Ocean Rig Corcovado and the Ocean Rig Olympia, we incurred debt obligations of $230.0 million, which has been repaid in full. In July 2009, DryShips acquired the remaining 25% of our total issued and outstanding capital stock from the minority interests held by third parties and entities controlled by our Chairman, President and Chief Executive Officer for a $50.0 million cash payment and the issuance of DryShips Series A Convertible Preferred Shares with an aggregate face value of $280.0 million, following which we became a wholly-owned subsidiary of DryShips.

On December 21, 2010, we completed the sale of an aggregate of 28,571,428 of our common shares (representing approximately 22% of our outstanding common shares) in the 2010 Private Offering. A company controlled by our Chairman, President and Chief Executive Officer, Mr. George Economou, purchased 2,869,428 common shares, or 2.38% of our outstanding common shares, in the 2010 Private Offering at the offering price of $17.50 per share. We received approximately $488.3 million of net proceeds from the private offering, of which we used $99.0 million to purchase our option contract with Samsung from DryShips, our parent company. We applied the remaining proceeds to partially fund remaining installment payments for our newbuilding drillships and general corporate purposes. Following the completion of the 2010 Private Offering, DryShips owned approximately 78% of our outstanding common shares.

On April 27, 2011, we completed the issuance of $500.0 million aggregate principal amount of 9.5% senior unsecured notes due 2016 offered in the 2011 Unsecured Bond Offering. The net proceeds of the 2011 Unsecured Bond Offering of approximately $487.5 million were used to finance our newbuilding drillships program and for general corporate purposes.

On August 26, 2011, we commenced the Exchange Offer to exchange up to 28,571,428 shares of our new common stock that were registered under the Securities Act pursuant to a registration statement on Form F-4 (Registration No. 333-175940), for an equivalent number of our common shares previously sold in the 2010 Private Offering. On September 29, 2011, an aggregate of 28,505,786 common shares were exchanged in the Exchange Offer.

On October 5, 2011, DryShips completed the partial spin off of our Company by distributing an aggregate of 2,967,291 common shares of the Company, representing approximately a 2.25% stake in the Company, after giving effect to the treatment of fractional shares, on a pro rata basis to DryShips's shareholders of record as of September 21, 2011. In lieu of fractional shares, DryShips's transfer agent aggregated all fractional shares that would otherwise be distributable to DryShips's shareholders and sold a total of 105 common shares on behalf of those shareholders who would otherwise be entitled to receive a fractional share of our Company. Following the distribution, each such shareholder received a cash payment in an amount equal to its pro rata share of the total net proceeds of the sale of fractional shares. On September 19, 2011, our common shares commenced "when issued" trading on the NASDAQ Global Select Market under the ticker "ORIGV." Our common shares commenced "regular way" trading on the NASDAQ Global Select Market under the ticker symbol "ORIG" on October 6, 2011.

On November 3, 2011, the OceanFreight merger was completed, following approval by shareholders of OceanFreight at a special meeting of shareholders held on November 3, 2011. Following the completion of the merger, OceanFreight is a wholly-owned subsidiary of DryShips. Under the terms of the merger agreement, OceanFreight shareholders received $11.25 cash and 0.52326 of a share of our common stock per share of OceanFreight common stock previously owned. Our common shares that comprised the stock portion of the merger consideration were previously outstanding shares that were owned by DryShips. Following the closing of the merger, DryShips transferred $33.1 million in cash and 1,541,159 shares of our common shares to shareholders of OceanFreight, other than the entities controlled by Mr. Anthony Kandylidis, the Chief Executive Officer of OceanFreight and our Executive Vice President. Prior to the completion of the merger, DryShips acquired from entities controlled by Mr. Kandylidis all of their shares of OceanFreight, representing a majority of the then outstanding shares of OceanFreight, for the same consideration per share that the OceanFreight shareholders received in the OceanFreight merger, the equity portion of which consisted of an aggregate of 1,570,226 of our common shares.

On April 17, 2012, DryShips completed the public offering of an aggregate of 11,500,000 of our common shares owned by DryShips. Companies affiliated with our Chairman and Chief Executive Officer purchased a total of 2,185,000 common shares from DryShips at the public offering price of $16.25 per share.

Effective as of June 2012, we issued an aggregate of 28,200 restricted common shares to our management and employees under the Ocean Rig UDW Inc. 2012 Equity Incentive Plan.

On September 20, 2012, Drill Rigs Holdings, our wholly-owned subsidiary, completed the issuance of $800 million of aggregate principal amount of Senior Secured Notes in the 2012 Secured Bond Offering. We used the net proceeds of the 2012 Secured Bond Offering to fully repay outstanding indebtedness under our $1.04 billion senior secured credit facility (amounting to $487.5 million as of June 30, 2012) and for the purposes of financing offshore drilling rigs, and to pay all fees and expenses associated therewith.

As of March 20, 2013, DryShips owned approximately 59.4% of our common shares.

Our Drilling Rigs

Our drilling rigs are marketed for offshore exploration and development drilling programs worldwide, with particular focus on drilling operations in ultra-deepwater and harsh environments. The Leiv Eiriksson, delivered in 2001, has a water depth drilling capacity of 7,500 feet. Since 2001, it has drilled 47 deepwater and ultra-deepwater wells as of March 2013 in a variety of locations, including Angola, Congo, Greenland, Turkey, Norway, the United Kingdom and Ireland, in addition to five shallow-water wells.

The Eirik Raude, delivered in 2002, has a water depth drilling capacity of 10,000 feet. Since 2002, it has drilled 74 deepwater and ultra-deepwater wells as of March 2013 in countries such as Canada, Ghana, Norway, Ivory Coast and the United Kingdom, and the Gulf of Mexico, in addition to six shallow-water wells.

For information on the employment of our drilling rigs, please see "Item 4. Information on the Company—B. Business Overview—Employment of our Fleet—Employment of Our Drilling Rigs."

Our Drillships

We took delivery of the Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos, our four sixth generation advanced capability ultra-deepwater drillships on January 3, 2011, March 30, 2011, July 28, 2011 and September 30, 2011, respectively. The total cost of construction and construction-related expenses for the Ocean Rig Corcovado the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos amounted to approximately $755.7 million, $756.9 million, $791.8 million and $784.4 million, respectively. Construction-related expenses include equipment purchases, commissioning, supervision and commissions to related parties, excluding financing costs.

In addition, we have entered into contracts with Samsung for the construction of four seventh generation drillships, the Ocean Rig Mylos, the Ocean Rig Skyros, the Ocean Rig Athena and the Ocean Rig Apollo, scheduled for delivery in July 2013, October 2013, November 2013 and January 2015, respectively, in connection with which we had made total payments of $879.4 million to Samsung, as of December 31, 2012. The total project cost per drillship, excluding financing costs, ranges between $668.0 million and $678.0 million.

For information on the employment of our drillships, please see "Item 4. Information on the Company—B. Business Overview—Employment of our Fleet—Employment of Our Drillships."

Management of Our Drilling Units

Our wholly-owned subsidiary, Ocean Rig AS, provides supervisory management services including onshore management, to our operating drilling rigs and drillships pursuant to separate management agreements entered into with each of the drilling unit-owning subsidiaries. In addition, Ocean Rig AS provides supervisory management services for our newbuilding drillships. Under the terms of these management agreements, Ocean Rig AS, through its offices in Stavanger, Norway, Aberdeen, United Kingdom and Houston, Texas, is responsible for, among other things, (i) assisting in construction contract technical negotiations, (ii) securing contracts for the future employment of the drillships; and (iii) providing commercial, technical and operational management for the drillships.

In addition, we have engaged Cardiff Drilling, a company controlled by our Chairman, President and Chief Executive Officer, Mr. George Economou, to provide us with consulting and other services with respect to the arrangement of employment for, and relating to the purchase and sale of, our drilling units. See "Item 7. Major Shareholders and Related Party Transacitons—B. Related Party Transactions—Services Agreements."

The services provided by Ocean Rig AS and Cardiff Drilling overlap mainly with respect to negotiating shipyard orders and providing marketing for potential contractors.

Previously, we had management agreements with Cardiff Marine pursuant to which Cardiff Marine provided supervisory services in connection with the construction of the Ocean Rig Corcovado and the Ocean Rig Olympia. These agreements were terminated effective December 21, 2010. See "—Management Fees to Related Party" below.

Factors Affecting Our Results of Operations

We charter our drilling units to customers primarily pursuant to long-term drilling contracts. Under the drilling contracts, the customer typically pays us a fixed daily rate, depending on the activity and up-time of the drilling unit. The customer bears all fuel costs and logistics costs related to transport to and from the unit. We remain responsible for paying the unit's operating expenses, including the cost of crewing, catering, insuring, repairing and maintaining the unit, the costs of spares and consumable stores and other miscellaneous expenses.

We believe that the most important measures for analyzing trends in the results of our operations consist of the following:

Employment Days: We define employment days as the total number of days the drilling units are employed on a drilling contract.

Dayrates or maximum dayrates: We define drilling dayrates as the maximum rate in U.S. Dollars possible to earn for drilling services for one 24 hour day at 100% efficiency under the drilling contract. Such dayrate may be measured by quarter-hour, half-hour or hourly basis and may be reduced depending on the activity performed according to the drilling contract.

Earnings efficiency / Earnings efficiency on hire: Earnings efficiency measures the effective earnings ratio, expressed as a percentage of the full earnings rate, after reducing for certain operations paid at a reduced rate, non-productive time at zero rate, or off hire without dayrates. Earnings efficiency on hire measures the earning efficiency only for the period during which the drilling unit is on contract and does not include off-hire periods.

Mobilization / demobilization fees: In connection with drilling contracts, we may receive revenues for preparation and mobilization of equipment and personnel or for capital improvements to the drilling vessels, dayrate or fixed price mobilization and demobilization fees.

Revenue: For each contract, we determine whether the contract, for accounting purposes, is a multiple element arrangement, meaning it contains both a lease element and a drilling services element, and, if so, identify all deliverables (elements). For each element we determine how and when to recognize revenue.

Term contracts: These are contracts pursuant to which we agree to operate the unit for a specified period of time. For these types of contracts, we determine whether the arrangement is a multiple element arrangement. For revenues derived from contracts that contain a lease, the lease elements are recognized as "Leasing revenues" in the statement of operations on a basis approximating straight line over the lease period. The drilling services element is recognized as "Service revenues" in the period in which the services are rendered at fair value rates. Revenues related to the drilling element of mobilization and direct incremental expenses of drilling services are deferred and recognized over the estimated duration of the drilling period.

Well contracts: These are contracts pursuant to which we agree to drill a certain number of wells. Revenue from dayrate based compensation for drilling operations is recognized in the period during which the services are rendered at the rates established in the contracts. All mobilization revenues, direct incremental expenses of mobilization and contributions from customers for capital improvements are initially deferred and recognized as revenues over the estimated duration of the drilling period.

Revenue from Drilling Contracts

Our drilling revenues are driven primarily by the number of drilling units in our fleet, the contractual dayrates and the utilization of the drilling units. This, in turn, is affected by a number of factors, including the amount of time that our drilling units spend on planned off-hire class work, unplanned off-hire maintenance and repair, off-hire upgrade and modification work, reduced dayrates due to reduced efficiency or non-productive time, the age, condition and specifications of our drilling units, levels of supply and demand in the rig market, the price of oil and other factors affecting the market dayrates for drilling units. Historically, industry participants have increased supply of drilling units in periods of high utilization and dayrates. This has resulted in an oversupply and caused a decline in utilization dayrates. Therefore, dayrates have historically been very cyclical.

Rig Operating Expenses

Rig operating expenses include crew wages and related costs, catering, the cost of insurance, expenses relating to repairs and maintenance, the costs of spares and consumable stores, shore based costs and other miscellaneous expenses. Our rig operating expenses, which generally represent fixed costs, have historically increased as a result of the business climate in the offshore drilling sector. Specifically, wages and vendor supplied spares, parts and services have experienced a significant price increase over the previous two to three years. Other factors beyond our control, some of which may affect the offshore drilling industry in general, including developments relating to market prices for insurance, may also cause these expenses to increase. In addition, these rig operating expenses are higher when operating in harsh environments, though an increase in expenses is typically offset by the higher dayrates we receive when operating in these conditions.

Depreciation

We depreciate our drilling units on a straight-line basis over their estimated useful lives. Specifically, we depreciate bare-decks over 30 years and other asset parts over five to 15 years. We expense the costs associated with a five-year periodic class work.

Management Fees to Related Party

From October 19, 2007 to December 21, 2010, we were party to, with respect to the Ocean Rig Corcovado and the Ocean Rig Olympia, separate management agreements with Cardiff Marine pursuant to which Cardiff Marine provided additional supervisory services in connection with these drillships including, among other things: (i) assisting in securing the required equity for the construction; (ii) negotiating, reviewing and proposing finance terms; (iii) assisting in marketing towards potential contractors; (iv) assisting in arranging, reviewing and supervising all aspects of building, equipment, financing, accounting, record keeping, compliance with laws and regulations; (v) assisting in procuring consultancy services from specialists; and (vi) assisting in finding prospective joint-venture partners and negotiating any such agreements. Pursuant to the management agreements, we paid Cardiff Marine a management fee of $40,000 per month per drillship plus (i) a chartering commission of 1.25% on revenue earned; (ii) a commission of 1.0% on the shipyard payments or purchase price paid for drillships; (iii) a commission of 1.0% on loan financing; and (iv) a commission of 2.0% on insurance premiums. In accordance with the Addenda No. 1 to the above management agreements, dated as of December 1, 2010, these management agreements were terminated effective December 21, 2010; however, all obligations to pay for services rendered by Cardiff Marine prior to termination remained in effect. As of December 31, 2010, these obligations totaled $5.8 million. For the years ended December 31, 2012, 2011 and 2010, total charges from Cardiff under the management agreement amounted to $0, $5.8 million and $4.0 million, respectively, which were capitalized as drillship under construction cost, being a cost directly attributable to the construction of the Ocean Rig Corcovado and the Ocean Rig Olympia.

General and Administrative Expenses

Our general and administrative expenses mainly include the costs of our offices, including salary and related costs for members of senior management and our shore-side employees.

Interest and Finance Costs

As of December 31, 2012, 2011 and 2010, we had total indebtedness of $2.9 billion, $2.78 billion and $1.26 billion, respectively. We capitalize our interest on the debt we have incurred in connection with our drillships under construction.

Critical Accounting Policies

Advances for drillships under construction: This represents amounts expended by us in accordance with the terms of the construction contracts for drillships as well as with a related party in connection with on-site supervision. In addition, interest costs incurred during the construction (until the asset is substantially complete and ready for its intended use) are capitalized. The carrying value of rigs and drillships under construction, or newbuildings, represents the accumulated costs at the balance sheet date. Cost components include payments for yard installments and variation orders, commissions to related party, construction supervision, equipment, or OFEs, spare parts, capitalized interest, certain non-reimbursable costs related to first time mobilization and commissioning costs. No charge for depreciation is made until commissioning of the newbuilding has been completed and it is ready for its intended use.

Capitalized interest: Interest expense is capitalized during the construction period of rigs and drillships based on accumulated expenditures for the applicable project at our current rate of borrowing. The amount of interest expense capitalized in an accounting period is determined by applying an interest rate, or the capitalization rate, to the average amount of accumulated expenditures for the asset during the period. The capitalization rates used in an accounting period are based on the rates applicable to borrowings outstanding during the period. We do not capitalize amounts in excess of actual interest expense incurred in the period. If our financing plans associate a specific new borrowing with a qualifying asset, we use the rate on that borrowing as the capitalization rate to be applied to that portion of the average accumulated expenditures for the asset that does not exceed the amount of that borrowing. If average accumulated expenditures for the asset exceed the amounts of specific new borrowings associated with the asset, the capitalization rate applied to such excess is a weighted average of the rates applicable to our other borrowings.

Drilling unit machinery and equipment, net: Drilling units are stated at historical cost less accumulated depreciation. Such costs include the cost of adding or replacing parts of drilling unit machinery and equipment when that cost is incurred, if the recognition criteria are met. The recognition criteria require that the cost incurred extends the useful life of a drilling unit. The carrying amounts of those parts that are replaced are written off and the cost of the new parts is capitalized. Depreciation is calculated on a straight- line basis over the useful life of the assets as follows: bare-deck, 30 years and other asset parts, 5 to 15 years. The residual values of the drilling rigs and drillships are estimated at $35 million and $50 million, respectively.

Drilling unit machinery and equipment, information technology and office equipment are recorded at cost and are depreciated on a straight-line basis over the estimated useful lives, for drilling unit machinery and equipment over 5 to 15 years and for information technology and office equipment over 5 years.

Intangible assets: Our finite-lived acquired intangible assets are recorded at historical cost less accumulated amortization. Amortization is recorded on a straight-line basis over the estimated useful lives of the intangibles as follows:

Intangible assets/liabilities	Years

Tradenames	10

Software	10

Trade names and software constitute the item "Intangible assets" in the Consolidated Balance Sheets. The amortization of these items are included in the line "Depreciation and amortization" in the Consolidated Statement of Operations.

Impairment of long-lived assets: We review for impairment long-lived assets and intangible long-lived assets held and used whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. In this respect, we review our assets for impairment on a rig by rig and drillship by drillship and asset by asset basis. When the estimate of undiscounted cash flows, excluding interest charges, expected to be generated by the use of the asset is less than its carrying amount, we evaluate the asset for impairment loss. The impairment loss is determined by the difference between the carrying amount of the asset and the fair value of the asset. We evaluate the carrying amounts of our drilling rigs and drillships by obtaining independent appraisals to determine if events have occurred that would require modification to their carrying values or useful lives. In evaluating useful lives and carrying values of long-lived assets, we review certain indicators of potential impairment, such as undiscounted projected operating cash flows, drilling rig/drillship sales and purchases, business plans and overall market conditions. In developing estimates of future undiscounted cash flows, we make assumptions and estimates about the drilling rigs' and drillships' future performance, with the significant assumptions being related to drilling rates, fleet utilization, operating expenses, capital expenditures, residual value and the estimated remaining useful life of each rig/drillship. The assumptions used to develop estimates of future undiscounted cash flows are based on historical trends as well as future expectations. To the extent impairment indicators are present, we determine undiscounted projected net operating cash flows for each rig/drillship and compare them to the rig or drillship's carrying value. The projected net operating cash flows are determined by considering the drilling revenues from existing drilling contracts for the fixed days and an estimated daily rate equivalent for the unfixed days. The salvage value used in the impairment test is estimated to be $35 million and $50 million for drilling rigs and drillships, respectively, in accordance with our depreciation policy. If our estimate of undiscounted future cash flows for any drilling rig or drillship is lower than the carrying value, the carrying value is written down, by recording a charge to operations, to the vessel's fair market value if the fair market value is lower than the vessel's carrying value. Our analysis for the year ended December 31, 2012, which also involved sensitivity tests on the drilling rates and fleet utilization (being the most sensitive inputs to variances), allowing for variances ranging from 97.5% to 92.5%, indicated no impairment on any of our drilling rigs or drillships. Although we believe that the assumptions used to evaluate potential impairment are reasonable and appropriate, such assumptions are highly subjective. There can be no assurance as to how long drilling rates and drilling rig and drillship values will remain at their currently high levels. As a result of the impairment review, we determined that the carrying amounts of its assets held for use were recoverable, and therefore, concluded that no impairment loss was necessary for 2010, 2011 and 2012.

Deferred financing costs: Deferred financing costs include fees, commissions and legal expenses associated with our long- term debt and are capitalized and recorded net with the underlying debt. These costs are amortized over the life of the related debt using the effective interest method and are included in interest expense. Unamortized fees relating to loans repaid or refinanced as debt extinguishments are expensed as interest and finance costs in the period the repayment or extinguishment is made.

Revenue and related expenses: Revenues: Our services and deliverables are generally sold based upon contracts with our customers that include fixed or determinable prices. We recognize revenue when delivery occurs, as directed by our customer, or the customer assumes control of physical use of the asset and collectability is reasonably assured. We evaluate if there are multiple deliverables within our contracts and whether the agreement conveys the right to use the drill rigs and drillships for a stated period of time and meet the criteria for lease accounting, in addition to providing a drilling services element, which are generally compensated for by dayrates. In connection with drilling contracts, we may also receive revenues for preparation and mobilization of equipment and personnel or for capital improvements to the drilling rigs or drillships and dayrate or fixed price mobilization and demobilization fees. Revenues are recorded net of agents' commissions. There are two types of drilling contracts: well contracts and term contracts.

Well contracts: Well contracts are contracts under which the assignment is to drill a certain number of wells. Revenue from dayrate-based compensation for drilling operations is recognized in the period during which the services are rendered at the rates established in the contracts. All mobilization revenues, direct incremental expenses of mobilization and contributions from customers for capital improvements are initially deferred and recognized as revenues and expenses, as applicable, over the estimated duration of the drilling period. To the extent that expenses exceed revenue to be recognized, they are expensed as incurred. Demobilization fees and expenses are recognized over the demobilization period. All revenues for well contracts are recognized as "Service revenues" in the statement of operations.

Term contracts: Term contracts are contracts under which the assignment is to operate the drilling unit for a specified period of time. For these types of contracts we determine whether the arrangement is a multiple element arrangement containing both a lease element and drilling services element. For revenues derived from contracts that contain a lease, the lease elements are recognized as "Leasing revenues" in the statement of operations on a basis approximating straight line over the lease period. The drilling services element is recognized as "Service revenues" in the period in which the services are rendered at fair value. Revenues related to the drilling element of mobilization and direct incremental expenses of drilling services are deferred and recognized over the estimated duration of the drilling periods. To the extent that expenses exceed revenue to be recognized, they are expensed as incurred. Demobilization fees and expenses are recognized over the demobilization period. Contributions from customers for capital improvements are initially deferred and recognized as revenues over the estimated duration of the drilling contract.

Income taxes: Income taxes have been provided for based upon the tax laws and rates in effect in the countries in which our operations are conducted and income is earned. There is no expected relationship between the provision for/or benefit from income taxes and income or loss before income taxes because the countries in which we operate have taxation regimes that vary not only with respect to the nominal rate, but also in terms of the availability of deductions, credits and other benefits. Variations also arise because income earned and taxed in any particular country or countries may fluctuate from year to year. Deferred tax assets and liabilities are recognized for the anticipated future tax effects of temporary differences between the financial statement basis and the tax basis of our assets and liabilities using the applicable jurisdictional tax rates in effect at the year end. A valuation allowance for deferred tax assets is recorded when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. We accrue interest and penalties related to its liabilities for unrecognized tax benefits as a component of income tax expense.

Inflation

Inflation has not had a material effect on our expenses given current economic conditions. In the event that significant global inflationary pressures appear, these pressures could increase our operating, administrative and financing costs.

Results of Operations

Included in this document are our audited consolidated historical financial statements for the years ended December 31, 2012, 2011 and 2010.

Year Ended December 31, 2012 Compared to Year Ended December 31, 2011

	Year Ended December 31, 2011			Year Ended December 31, 2012			Change			Percentage Change

REVENUES:
Total revenues		699,649			941,903			242,254			34.6	%

EXPENSES:
Drilling rigs and drillships operating expenses		281,833			563,583			281,750			100.0	%

Depreciation		162,532			224,479			61,947			38.1	%
Loss on disposals		754			133			(621	)		-82.4	%
General and administrative expenses		46,718			83,647			36,929			79.0	%
Legal settlements and other, net		-			4,524			4,524			-
Operating income		207,812			65,537			(142,275	)		-68.5	%

OTHER INCOME/(EXPENSES):
Interest and finance costs		(63,752	)		(116,427	)		(52,675	)		82.6	%
Interest income		9,810			553			(9,257	)		-94.4	%
Loss on interest rate swaps		(33,455	)		(36,974	)		(3,519	)		10.5	%
Other, net		2,311			(1,068	)		(3,379	)		-146.2	%
Total other income/(expenses),net		(85,086	)		(153,916	)		(68,830	)		80.9	%

Net income/(loss) before taxes		122,726			(88,379	)		(211,105	)		-172.0	%
Income Taxes		(27,428	)		(43,957	)		(16,529	)		60.3	%
Net Income/(Loss)		95,298			(132,336	)		(227,634	)		-238.9	%

Revenues

Revenues from drilling contracts increased by $242.3 million, or 34.6%, to $941.9 million for the year ended December 31, 2012, as compared to $699.6 million for the year ended December 31, 2011. The increase is primarily attributable to the operation of the Ocean Rig Mykonos and the Ocean Rig Poseidon that commenced drilling activities after the third quarter of 2011, which contributed $353.0 million in aggregate revenues during the year ended December 31, 2012, as compared to $78.4 million in aggregate revenues during the same period in 2011. Further, the Ocean Rig Olympia and the Ocean Rig Corcovado, which commenced drilling activities during the first and second quarters of 2011, respectively, contributed $291.9 million in aggregate revenues during the year ended December 31, 2012, as compared to $219.5 million in aggregate revenues during the same period in 2011, which were offset by decreased revenues amounting to an aggregate of $94.3 million contributed by the Leiv Eiriksson and the Eirik Raude, due to lower rates and utilization during 2012. The maximum dayrates for the contracts on which our drilling units were employed during the year ended December 31, 2012, ranged between approximately $441,000 and $675,000 per day. The maximum day rates for the contracts on which our drilling units were employed during the year ended December 31, 2011, ranged between approximately $415,000 and $665,473 per day. Revenues for the year ended December 31, 2012, also include $24.6 million for loss of hire insurance recovery related to Ocean Rig Corcovado.

Operating expenses

Drilling rigs and drillships operating expenses increased by $281.8 million, or 100.0%, to $563.6 million for the year ended December 31, 2012, compared to $281.8 million for the year ended December 31, 2011. The increase in operating expenses was mainly due to the commencement of drilling operations of the Ocean Rig Mykonos and the Ocean Rig Poseidon, resulting in operating expenses of $159.3 million in total during the year ended December 31, 2012, as compared to operating expenses of $33.1 million in total for the same period in 2011. In addition, for the year ended December 31, 2012, the operating expenses relating to the Leiv Eiriksson, the Eirik Raude and the Ocean Rig Corcovado increased by $116.4 million, mainly due to a more extensive maintenance program and upgrades performed during the year ended December 31, 2012. Furthermore, operating expenses related to the Ocean Rig Olympia increased by $25.3 million during year ended December 31, 2012, due to the fact that the drillship operated for the entire period, as compared to the year ended December 31, 2011, when the drillship operated for a shorter period. Further, a growing resource team of technicians contributed $13.8 million of operating expenses during year ended December 31, 2012.

Depreciation and amortization expense

Depreciation and amortization expense for the drilling units increased by $62.0 million, or 38.2%, to $224.5 million for the year ended December 31, 2012, as compared to $162.5 million for the year ended December 31, 2011. The increase in depreciation and amortization expense was mainly attributable to the aggregate of $72.9 million of depreciation expense related to the depreciation of the Ocean Rig Poseidon and the Ocean Rig Mykonos, which were delivered during the third quarter of 2011, as compared to an aggregate of $23.1 million of depreciation expense for the same period in 2011. In addition, the Ocean Rig Olympia contributed $8.9 million more in depreciation expense for the year ended December 31, 2012, as compared to the same period of 2011, due to the Company's ownership of the drillship for the full year ended December 31, 2012. The Ocean Rig Corcovado also contributed $3.9 million more in depreciation expense during 2012 due to upgrades performed early this year.

Loss on disposals

Loss on asset disposals amounted to $0.1 million for the year ended December 31, 2012, while for the relevant period in 2011, there was a loss amounting to $0.8 million, related to disposal of office equipment.

General and administrative expenses

General and administrative expenses increased by $36.9 million, or 79.0%, to $83.6 million for the year ended December 31, 2012, as compared to $46.7 million for year ended December 31, 2011. This increase is mainly due to increased costs related to the management of a larger fleet, as well as expenses related to the operation of the Company's office in Brazil that commenced operations in late 2011.

Legal Settlements and other, net

The amount of $4.5 million consists of $6.4 million (loss) in legal settlements which is mainly related to a claim settlement related to import/export taxes duties in Angola that was settled during the second quarter of 2012, offset by a $1.9 million gain related to a settlement of an old dispute with one of our contractors. No such items are included in the relevant period of 2011.

Interest and finance costs

Interest and finance costs increased by $52.6 million, or 82.4%, to $116.4 million for year ended December 31, 2012, compared to $63.8 million for the year ended December 31, 2011. The increase is mainly associated with a higher level of debt during the year ended December 31, 2012, as compared to the corresponding period of 2011. In addition, capitalized interest and amortization of financing costs decreased by $12.8 million and $4.8 million, respectively.

Interest income

Interest income decreased by $9.2 million, or 93.9%, to $0.6 million for the year ended December 31, 2012, compared to $9.8 million for the year ended December 31, 2011. The decrease was mainly due to lower interest rates on our deposits during 2012 as compared to 2011.

Loss on interest rate swaps

Losses on interest rate swaps increased by $3.5 million, or 10.5%, to $37.0 million for year ended December 31, 2012, as compared to $33.5 million for the year ended December 31, 2011. The loss for the year ended December 31, 2012, was mainly due to discontinued cash flow hedges amortization increase by approximately $13.0 million due to repayment of the Company's $1.04 billion credit facility, partially offset by favorable trends of mark to market losses of outstanding swap positions..

Other, net

Other, net decreased by $3.4 million, or 147.8% to a loss of $1.1 million for year ended December 31, 2012, compared to a gain of $2.3 million for the year ended December 31, 2011. The decrease is mainly due to foreign currency exchange rate differences.

Income taxes

Income taxes increased by $16.6 million, or 60.6%, to $44.0 million for year ended December 31, 2012, compared to $27.4 million for the year ended December 31, 2011. Because our drilling units operate around the world, they may become subject to taxation in many different jurisdictions. The basis for such taxation depends on the relevant regulation in the countries in which we operate. Consequently, there is no expected relationship between the income tax expense or benefit for the period and the income or loss before taxes.

Year Ended December 31, 2011 Compared to Year Ended December 31, 2010

(U.S. Dollars in thousands)	Year Ended December 31, 2010			Year Ended December 31, 2011			Change			Percentage Change
REVENUES:
Total revenues		405,712			699,649			293,937			72.4	%

EXPENSES:
Drilling rigs and drillships operating expenses		119,369			281,833			162,464			136.1	%
Depreciation and amortization		75,092			162,532			87,440			116.4	%
Loss on disposals		1,458			754			(704	)		(48.3	%)
General and administrative expenses		20,566			46,718			26,152			127.2	%
Operating income		189,227			207,812			18,585			9.8	%

OTHER INCOME / (EXPENSES):
Interest and finance costs		(8,418)			(63,752)			55,334			657.3	%
Interest income		12,464			9,810			(2,654	)		(21.3	%)
Loss on interest rate swaps		(40,303	)		(33,455	)		6,848			(17.0	%)
Other, net		2,227			2,311			84			3.8	%
Total other income/(expenses), net		(34,030)			(85,086)			51,056			150.0	%

Net Income/(loss) before taxes		155,197			122,726			(32,471	)		(20.9	%)
Income taxes		(20,436	)		(27,428	)		(6,992	)		34.2	%
Net Income/(Loss)	$	134,761		$	95,298		$	(39,463	)		(29.3	%)

Revenues

Revenues from drilling contracts increased by $293.9 million, or 72.4%, to $699.6 million for the year ended December 31, 2011, as compared to $405.7 million for the year ended December 31, 2010. The increase is primarily attributable to the operation of our six drilling units (two drill rigs and four drillships) in 2011, compared to the operation of two drill rigs in 2010. The Ocean Rig Olympia, Ocean Rig Corcovado and Ocean Rig Poseidon were delivered and commenced drilling activities during the year ended December 31, 2011. The day rates for the contracts on which our drilling units were employed during the year ranged between $415,000 and $665,473 per day.

Operating expenses

Drilling rigs and drillships operating expenses increased by $162.4 million, or 136.0%, to $281.8 million for the year ended December 31, 2011, compared to $119.4 million for the year ended December 31, 2010. The increase in operating expenses of $162.5 million is mainly due to $132.3 million in increased operating expenses from the commencement of drilling operations of the Ocean Rig Corcovado, the Ocean Rig Olympia, the Ocean Rig Poseidon and the Ocean Rig Mykonos during 2011, $15.3 million related to the 10-year class survey of the Leiv Eiriksson and $15.0 million in increased operating expenses relating to the Eirik Raude due to a more extensive maintenance program performed during 2011.

Depreciation and amortization expense

Depreciation and amortization expense for the drilling rigs and drillships increased by $87.4 million, or 116.4%, to $162.5 million for the year ended December 31, 2011, as compared to $75.1 million for the year ended December 31, 2010. The increase in depreciation and amortization was attributable to the depreciation related to our four operating drillships delivered during 2011.

Loss on disposal of assets

Loss on disposal of assets amounting to $0.8 million and $1.5 million for the years ended December 31, 2011 and 2010, respectively, related to the disposal of rig equipment.

General and administrative expenses

General and administrative expenses increased by $26.1 million, or 126.7%, to $46.7 million for the year ended December 31, 2011, as compared to $20.6 million for the year ended December 31, 2010. The increase of $20.9 million is mainly due to increased costs relating to the management of six drilling units during the year ended December 31, 2011, as compared to two drilling units during the year ended December 31, 2010, as well as professional fees related to our exchange offer completed in September 2011.

Interest and finance costs

Interest and finance costs increased by $55.4 million, or 659.5%, to $63.8 million for the year ended December 31, 2011, compared to $8.4 million for the year ended December 31, 2010. The increase is mainly due to higher average debt, costs associated with debt issuance and increased interest rates during 2011.

Interest income

Interest income decreased by $2.7 million, or 21.6%, to $9.8 million for the year ended December 31, 2011, compared to $12.5 million for the year ended December 31, 2010. The decrease was due to lower interest rates on our deposits during 2011, although the average cash balances increased significantly during the same period.

Loss on interest rate swaps

Loss on interest rate swaps decreased by $6.8 million, or 16.9%, to $33.5 million for the year ended December 31, 2011, compared to a loss of $40.3 million for the year ended December 31, 2010. The loss for the year ended December 31, 2011 is mainly due to mark to market losses of outstanding swap positions as interest rates trended downwards.

Other, net

Other, net increased by $0.1 million, or 4.5%, to a gain of $2.3 million for the year ended December 31, 2011, compared to a gain of $2.2 million for the year ended December 31, 2010. The increase is due to foreign exchange gain, which was offset by net losses on currency forward contracts.

Income taxes

Income taxes increased by $7.0 million, or 34.3%, to $27.4 million for the year ended December 31, 2011, compared to $20.4 million for the year ended December 31, 2010. As our drilling units operate around the world, they may become subject to taxation in many different jurisdictions. The basis for such taxation depends on the relevant regulation in the countries in which we operate. Consequently, there is no expected relationship between the income tax expense or benefit for the period and the income or loss before taxes.

B. Liquidity and Capital Resources

As of December 31, 2012, we had $192.7 million of restricted cash relating mainly to: (i) bank deposits which are blocked or pledged as cash collateral; and (ii) required minimum cash and cash equivalents. Our restricted cash balances as of December 31, 2012 increased by $10.6 million, or 5.8%, to $192.7 million, compared to $182.1 million as of December 31, 2011. The increase in restricted cash balances was primarily due to an increase of $65.8 million in aggregate restricted cash related to our Deutsche Bank credit facilities and cash collateral required by a new swap agreement. This increase was primarily offset by a decrease of $55.0 million in aggregate restricted cash related to the repayment of our $1.04 billion senior secured credit facility and the amendment to our $800.0 million senior secured term loan agreement.

As of December 31, 2012, we had $317.4 million of cash and cash equivalents. Our cash and cash equivalents increased by $66.5 million, or 26.5%, to $317.4 million as of December 31, 2012, compared to $250.9 million as of December 31, 2011. The increase in our cash and cash equivalents relates mainly to the receipt of $800.0 million in gross proceeds from the issuance and sale of Senior Secured Notes in the 2012 Secured Bond Offering and net cash provided by operating activities of $278.3 million, which were partly offset by payments of yard installments and capital upgrades amounting to $310.1 million in the aggregate and loan repayments amounting to $671.7 million in the aggregate.

As of December 31, 2012 and December 31, 2011, we had total indebtedness, on a consolidated basis, of $2.9 billion and $2.7 billion, respectively, under our outstanding debt agreements, excluding unamortized financing fees. Our total indebtedness as of December 31, 2012 increased by $0.2 billion, or 7.4%, to $2.9 billion, compared to $2.7 billion as of December 31, 2011 due to the issuance and sale of $800 million aggregate principal amount of Senior Secured Notes in the 2012 Secured Bond Offering, which was partly offset by payments and repayments of long- and short-term loans.

As of December 31, 2012, we had no available borrowing capacity under our secured credit facilities and aggregate debt outstanding of $2.9 billion. However, as discussed below, we entered into a $1.35 billion secured term loan facility in February 2013, under which we have borrowing capacity of $1.35 billion. As of December 31, 2012, we were in compliance with all covenants related to our outstanding debt agreements. Please refer to the discussion on Long-term Debt as detailed in Note 9 of our audited consolidated financial statements.

As of December 31, 2012, our total purchase commitments consisted of the remaining construction expenses of approximately $1.6 billion relating to the construction of our four seventh generation drillships under construction, which are scheduled to be delivered in July 2013, October 2013, November 2013 and January 2015, respectively. The estimated total project cost per drillship for our seventh generation drillships under construction, excluding financing costs, ranges between $668.0 million and $678.0 million. As of December 31, 2012, we made pre-delivery payments of $879.4 million in the aggregate for these newbuilding drillships. The remaining total construction payments for these drillships, excluding financing costs, amounted to approximately $1.6 billion in the aggregate as of December 31, 2012. We plan to finance these remaining payments, which are due upon delivery of the drillships, with new debt or equity financing, which we have not yet secured in full. In February 2013, we entered into a $1.35 billion senior secured term loan facility to partially finance the construction costs of our three seventh generation drillships scheduled for delivery in 2013. We cannot be certain that we will be able to obtain the additional financing we need to complete the acquisition of our seventh generation drillships on acceptable terms or at all.

We may exercise our options under our contract with Samsung to purchase up to two additional newbuilding drillships any time on or prior to March 31, 2013. To the extent we exercise any of these options, we will incur additional payment obligations for which we have not arranged financing.

Working capital is defined as current assets minus current liabilities (including the current portion of long-term debt). Our working capital surplus amounted to $91.5 million as of December 31, 2012, as compared to a working capital surplus of $68.9 million as of December 31, 2011. The increase in working capital surplus as of December 31, 2012, as compared to December 31, 2011, is primarily due to our increased cash balance and the decrease of the debt falling due within a year.

Our principal use of funds has been capital expenditures to establish and grow our fleet, maintain the quality of our drilling units, comply with international standards, environmental laws and regulations, fund working capital requirements and make principal repayments on outstanding loan facilities. Since our formation, our principal source of funds has been equity provided by our shareholders, operating cash flows, our equity and notes offerings and long-term bank borrowings. From January 1, 2009 to December 3, 2010, we received $1.3 billion in cash from our parent company, DryShips, in the form of capital contributions to meet obligations for capital expenditures on our drillships under construction and debt repayments during the period. In 2011, we did not receive cash capital contributions from DryShips. In March and April 2011, we borrowed an aggregate amount of $175.5 million from DryShips through shareholder loans, which we repaid in full in April 2011. Based on our current liquidity position, we do not expect to require funding from DryShips over the next 12 months. As we are no longer a wholly owned subsidiary of DryShips, even if it is able to do so, DryShips may be unwilling to provide continued funding or credit support for our capital expenditure requirements or only provide such funding in return for market rate repayment and interest rates or issuances of equity securities, which could be significantly dilutive to other shareholders.

Our internally generated cash flow is directly related to our business and the market sectors in which we operate. Should the drilling market deteriorate, or should we experience poor results in our operations, cash flow from operations may be reduced. As of December 31, 2012, assuming the drilling or financing markets do not deteriorate, we believe that our current cash balances and operating cash flow, together with the proceeds of any debt or equity issuances in the future, will be sufficient to meet our liquidity needs for the next 12 months, including minimum cash requirements under our secured credit facilities, under which $176.7 million is due in 2013 and our newbuilding contracts, under which an aggregate of approximately $1.2 billion is due in 2013. Our access to debt and equity markets may be reduced or closed due to a variety of events, including a credit crisis, credit rating agency downgrades of our debt, industry conditions, general economic conditions, market conditions and market perceptions of us and our industry.

Compliance with Covenants under Our Debt Agreements

Our debt agreements, including the indenture governing our Senior Secured Notes, impose operating and financial restrictions on us. These restrictions generally limit our ability to, among other things (i) pay dividends; (ii) incur or guarantee additional indebtedness; (iii) create or permit liens on our assets; (iv) change the management and/or ownership of the drilling units; (v) change the general nature of their business; (vi) consummate a merger, consolidation or sale of our drilling units or the shares of our subsidiaries; (vii) make investments; and (viii) enter into transactions with affiliates.

In addition, our secured credit facilities, which are secured by mortgages on our operating drillships, require us and certain of our subsidiaries to maintain specified financial ratios and satisfy certain financial covenants, including the requirement that that the market value of the mortgaged drillships under the applicable credit facility, determined in accordance with the terms of that facility, does not fall below a certain percentage of the outstanding amount of the loan, which we refer to as a value maintenance clause. In general, these financial covenants relate to the maintenance of (i) minimum amount of free cash; (ii) leverage ratio not to exceed specified levels; (iii) minimum interest coverage ratio; (iv) minimum current ratio (the ratio of current assets to current liabilities); and (v) minimum equity ratio (the ratio of value adjusted equity to value adjusted total assets). Any future credit agreement or amendment or debt instrument we enter into may contain similar or more restrictive covenants.

Events beyond our control, including changes in the economic and business conditions in the deepwater offshore drilling market in which we operate, may affect our ability to comply with these ratios and covenants. Our ability to maintain compliance will also depend substantially on the value of our assets, our dayrates, our ability to obtain drilling contracts, our success at keeping our costs low and our ability to successfully implement our overall business strategy. We cannot guarantee that we would be able to obtain our lenders' waiver or consent with respect to any noncompliance with the specified financial ratios and financial covenants under our various credit facilities or future financial obligations or that we would be able to refinance any such indebtedness in the event of default.

The restrictions, ratios and financial covenants in our debt agreements could limit our ability to fund our operations or capital needs, make acquisitions or pursue available business opportunities, which in turn may adversely affect our financial condition. A violation of any of these provisions could result in a default under our existing and future debt agreements which could allow all amounts outstanding thereunder to be declared immediately due and payable. This would likely in turn trigger cross-acceleration and cross-default rights under the terms of our indebtedness outstanding at such time. If the amounts outstanding under our indebtedness were to be accelerated or were the subject of foreclosure actions, we cannot assure you that our assets would be sufficient to repay in full the money owed to the lenders or to our other debt holders.

As of December 31, 2012, we were in compliance with all covenants related to our debt agreements.

If our indebtedness is accelerated pursuant to the cross-default or cross-acceleration provisions contained therein, it will be very difficult in the current financing environment for us to refinance our debt or obtain additional financing and we could lose our drilling units if any of our lenders or the trustee and collateral agent under the indenture governing our Senior Secured Notes move to foreclose their liens on the collateral securing the agreements. We expect that cash on hand and cash generated from operations would be sufficient to repay our facilities that have cross-default provisions, which amounted to approximately $2.4 billion in the aggregate, excluding our 9.5% senior unsecured notes, as of December 31, 2012. However, in the event we do not have sufficient cash on hand and cash generated from operations to repay our indebtedness that has cross-default provisions, if that debt were to be accelerated by our lenders or the trustee or noteholder collateral agent, we would have to seek to access the capital markets to fund the mandatory payments and we cannot guarantee that such financing will be available on attractive terms or at all.

Recent Amendments to Our Debt Agreements

Prior to the amendments discussed below, our secured credit facilities also contained cross-default or cross-acceleration clauses relating to DryShips's indebtedness for its drybulk carrier and tanker fleet.

On May 14, 2012, we and two of our wholly owned subsidiaries signed amendments to our two Deutsche Bank credit facilities to, among other things, remove the payment guarantee of DryShips, subject to reinstatement as discussed below, and remove the financial covenants for DryShips and the cross-default provision relating to DryShips's outstanding indebtedness for its drybulk carrier and tanker fleet. As a result of the amendments, a default by DryShips under one of its loan agreements for its drybulk carrier and tanker fleet will not result in a cross-default under the Deutsche Bank credit facilities that would provide the lenders thereunder with the right to accelerate our outstanding debt. In addition, the amendments removed the automatic prepayment mechanism under the Deutsche Bank credit facilities. Also, by the end of September 2014, we are required to maintain an additional $57.0 million in the aggregate in the debt service reserve relating to the facilities. Furthermore, under the amended Deutsche Bank credit facilities, we are permitted to pay dividends, make distributions and effect redemptions or returns of share capital in an amount of up to 50% of net income, provided we maintain minimum liquidity in an aggregate amount of not less than $200.0 million in cash and cash equivalents and restricted cash and provide evidence to the lenders through cash flow forecasts that we will maintain such level for the next 12 months following the date of the dividend, distribution or redemption or return of share capital. The borrowers under the amended Deutsche Bank credit facilities are prohibited from paying dividends or making distributions to us or effecting redemptions, repayments or reductions of share capital, except following earnings deposit dates and unless all relevant primary transfers have been made, we maintain certain minimum balances in the debt service reserve accounts and no default has occurred, is continuing or will result from the payment. Notwithstanding the foregoing, in the case of the facility for the Ocean Rig Mykonos, the borrower may pay dividends to us upon earnings deposit dates in connection with (i) rebates of Brazilian import taxes incurred prior to May 14, 2012, (ii) the repayment of loans made by us to the borrower in respect of certain capital expenditures and operating expenses incurred prior to May 14, 2012; and (iii) any amounts paid by us following May 14, 2012 in respect of certain capital expenditures and operating expenses in excess of certain budgeted amounts, provided in each case all relevant primary transfers have been made. In addition, under the facility for the Ocean Rig Poseidon, Ocean Rig Poseidon Operations Inc., the borrower, is also prohibited from paying dividends or making distributions to us or effecting redemptions, repayments or reductions of share capital other than out of funds released from the bareboat charter proceeds account during the term of the bareboat charter in respect of the contract with Petrobras Tanzania for the Ocean Rig Poseidon.

Under the terms of the amended Deutsche Bank credit facilities, in the event of a breach by us of any of the financial covenants contained in our guarantees under the Deutsche Bank credit facilities, the unconditional and irrevocable payment guarantees of DryShips will be reinstated, pursuant to which DryShips will be obligated to pay, upon demand by the lenders, any amount outstanding under the credit facilities upon a failure by us to pay such amount. In addition, DryShips will be required to indemnify the lenders in respect of any losses they incur in respect of any amounts due under the loans that are not recoverable from DryShips under the guarantees and that we fail to pay. The amount payable by DryShips under the guarantees will be limited to $214.0 million with respect to the facility for the Ocean Rig Poseidon and $255.0 million with respect to the facility for the Ocean Rig Mykonos, in each case plus any other amounts that become payable in connection with the payment of such amount. The guarantees will not include any financial covenants applicable to DryShips or cross-default provisions in relation to DryShips's indebtedness for its drybulk carrier and tanker fleet. The Deutsche Bank credit facilities finance the Ocean Rig Poseidon and the Ocean Rig Mykonos. If these guarantees were to be reinstated, and subsequently were to become invalid or unenforceable for any reason, we would potentially be required to prepay the facilities.

On May 9, 2012, we and one of our other wholly owned operating subsidiaries, Drillships Holdings Inc., signed an amendment under our $800.0 million secured term loan agreement with Nordea Bank as agent to, among other things, terminate the guarantee by DryShips and remove the related covenants and remove the cross-acceleration provisions relating to DryShips's indebtedness for its drybulk carrier and tanker fleet and our indebtedness under our other credit facilities. As a result of the amendment, a default by DryShips under one of its loan agreements for its drybulk carrier and tanker fleet or a default by us under one of our other credit facilities and the acceleration of the related debt will not result in a cross-default under our $800.0 million secured term loan agreement that would provide our lenders with the right to accelerate the outstanding debt under the loan agreement. In addition, under the terms of the loan agreement, as amended, (i) we are permitted to buyback our common shares; (ii) Drillships Holdings Inc. is permitted to pay dividends to us as its shareholder; and (iii) we are permitted to pay dividends to our shareholders of up to 50% of our net income of each previous financial year, provided in each case that we maintain minimum liquidity in an aggregate amount of not less than $200.0 million in cash and cash equivalents and restricted cash and maintain such level for the next 12 months following the date of the dividend payment. The amendments also provide for a reduction in the amount of minimum free cash required to be maintained by Drillships Holdings Inc. from $75.0 million to $50.0 million. Under the agreement, we are required to maintain minimum free cash of $100.0 million. Amounts outstanding under this facility are secured by the Ocean Rig Corcovado and the Ocean Rig Olympia.

In addition, on May 18, 2012, we and Drill Rigs Holdings Inc. amended our $1.04 billion credit facility with DNB Bank ASA, as agent, to, among other things, remove the cross-acceleration clause relating to DryShips's indebtedness for its drybulk carrier and tanker fleet. We repaid in full the outstanding indebtedness under our $1.04 billion credit facility, which was $487.5 million as of June 30, 2012, using the net proceeds of our 2012 Secured Bond Offering.

Our Debt Agreements

Existing Debt Agreements

6.50% senior secured notes due 2017

On September 20, 2012, Drill Rigs Holdings, our wholly-owned subsidiary, or the Issuer, completed the issuance of $800 million aggregate principal amount of Senior Secured Notes pursuant to an indenture in the 2012 Secured Bond Offering. The Senior Secured Notes and are fully and unconditionally guaranteed, on a senior secured basis, by us and certain existing and future subsidiaries of the Issuer, or the Subsidiary Guarantors, including subsidiaries of the Issuer that holds or will hold the Leiv Eiriksson or the Eirik Raude, or certain assets related to such drilling rigs, or that is or becomes party to a drilling contract in respect of either the Leiv Eiriksson or the Eirik Raude.

The Senior Secured Notes are secured, on a first priority basis, by a security interest in the Leiv Eiriksson and the Eirik Raude and certain other assets of the Issuer and Subsidiary Guarantors, assignments of all earnings and insurance proceeds related to the two drilling rigs, and by a pledge of the stock of the Issuer and the Subsidiary Guarantors.

The Senior Secured Notes mature on October 1, 2017, and bear interest from the date of their issuance at the rate of 6.50% per annum. Interest on outstanding Senior Secured Notes is payable semi-annually in arrears, commencing on April 1, 2013. The net proceeds, after fees and expenses, of the 2012 Secured Bond Offering of approximately $782.0 million were used to fully repay outstanding indebtedness under our $1.04 billion senior secured credit facility described below under "—Repaid Debt Agreements—$1.04 billion secured credit facility," amounting to $487.5 million as of June 30, 2012, and for the purposes of financing offshore drilling rigs, and to pay all fees and expenses associated therewith.

The Senior Secured Notes rank equally in right of payment with all of the Issuer's existing and future senior indebtedness and senior in right of payment to any of the Issuer's existing and future subordinated indebtedness. The guarantees of each guarantor are senior obligations of that guarantor and rank equally in right of payment with all of that guarantor's existing and future senior indebtedness, including guarantees, and senior in right of payment to all of that guarantor's existing and future subordinated indebtedness.

At any time on or after October 1, 2015, the Issuer may redeem some or all of the Senior Secured Notes at specified redemption prices, plus accrued and unpaid interest on the Senior Secured Notes redeemed. Prior to October 1, 2015, the Issuer may, at its option, redeem up to 35% of the aggregate original principal amount of the Senior Secured Notes with the net proceeds of one or more equity offering at a price equal to 106.500% of the principal amount thereof, plus accrued and unpaid interest thereon to the date of redemption. In addition, prior to October 1, 2015, the Issuer may redeem all or a portion of the Senior Secured Notes at a redemption price equal to 100% of the outstanding principal amount thereof, plus any accrued and unpaid interest thereon to the date of redemption, plus a "make whole" premium. Also prior to October 1, 2015, the Issuer may, not more than once in any twelve-month period, redeem up to 10% of the original principal amount of the Senior Secured Notes at a redemption price equal to 103% of the principal amount thereof, plus any accrued and unpaid interest thereon to the date of redemption.

If a change of control, as defined in the indenture, occurs, each holder of Senior Secured Notes will have the right to require the repurchase of all or any part of its Senior Secured Notes at a price equal to 101% of their original principal amount, plus accrued and unpaid interest to the date of repurchase. In addition, the Issuer may be required to offer to use all or a portion of the net proceeds of certain asset sales to purchase some or all of the Senior Secured Notes at 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the date of purchase.

The indenture governing the Senior Secured Notes, among other things, limits the ability of us and our restricted subsidiaries thereunder, including the Issuer, to: (i) incur or guarantee additional indebtedness or issue preferred stock or disqualified capital stock; (iii) pay dividends, redeem equity interests or subordinated indebtedness or make other restricted payments; (iv) transfer or sell assets; (v) incur dividend or other payment restrictions affecting restricted subsidiaries; (vii) enter into transactions with affiliates; (ix) engage in businesses other than a business that is the same as our current business and any reasonably related businesses; and (viii) designate subsidiaries as unrestricted subsidiaries. In addition, the indenture also restricts the Issuer's ability and the ability of us and the other guarantors to, among other things, (i) create or incur liens; (ii) consummate a merger, consolidation or sale of all or substantially all of the assets of the Issuer, us or the other guarantors; and (iii) take or omit to take any actions that would adversely affect or impair in any material respect the collateral securing the Senior Secured Notes. Subject to certain exceptions, our future subsidiaries will become restricted subsidiaries under the indenture governing the Senior Secured Notes and, under limited circumstances, may also become guarantors of the Senior Secured Notes.

The Senior Secured Notes are listed on the Official List of the Irish Stock Exchange and trade on the Global Exchange Market of that exchange.

$1.35 billion secured term loan facility

On February 28, 2013, Drillships Ocean Ventures Inc., our wholly-owned subsidiary, entered into a secured term loan facilities agreement with a syndicate of lenders and DNB Bank ASA, as facility agent and security agent, in the amount of $1.35 billion to partially finance the construction costs of the Ocean Rig Mylos, the Ocean Rig Skyros and the Ocean Rig Athena, our seventh generation drillships scheduled for delivery in July 2013, October 2013 and November 2013, respectively. The facilities agreement is comprised of three term loan facilities of up to $150.0 million each (one relating to each of the aforementioned seventh generation drillships) made available by the commercial lenders, or the Commercial Facilities, three term loan facilities of up to $150.0 million each (one relating to each of the aforementioned seventh generation drillships) made available by Eksportkreditt Norge AS, or the Eksportkreditt GIEK Facilities, and three term loan facilities of up to $150.0 million each (one relating to each of the aforementioned seventh generation drillships) made available by The Export-Import Bank of Korea, or the Kexim Facilities. The term loan facilities with respect to the Ocean Rig Mylos bear interest at LIBOR plus a margin and are repayable beginning in the fourth quarter of 2013 in 45 quarterly installments of an aggregate of $10.0 million through the fourth quarter of 2024. The term loan facilities with respect to the Ocean Rig Skyros and the Ocean Rig Athena bear interest at LIBOR plus a margin and are repayable beginning in the first quarter of 2014 in 42 quarterly installments of an aggregate of approximately $10.5 million per drillship for the first 19 installment payments and $10.9 million per drillship for the final 23 installment payments through the second quarter of 2024.

The $1.35 billion secured term loan facility is secured by, among other things, a first priority mortgage over the Ocean Rig Mylos, the Ocean Rig Skyros and the Ocean Rig Athena, a first priority pledge of the borrower's and/or the guarantors' (as the case may be) earnings accounts, a first priority assignment of all earnings and insurances in respect of the mortgaged vessels, a pledge of the shares of capital stock of certain of our subsidiaries and guarantees from Ocean Rig UDW Inc. and certain of our subsidiaries.

Under the $1.35 secured term loan facility, we, the borrower and certain of our other subsidiaries, as guarantors, are subject to certain financial covenants requiring among other things, the maintenance of (i) a minimum amount of cash and cash equivalents; (ii) a leverage ratio not to exceed specified levels; (iii) a minimum interest coverage ratio; (iv) a minimum current ratio; and (v) a minimum equity ratio. In addition, the aggregate market value of the Ocean Rig Mylos, the Ocean Rig Skyros and the Ocean Rig Athena, following the delivery date of the first drillship, must be greater than 140% of the total borrowings outstanding under the facility.

The $1.35 billion secured term loan facility also contains other customary restrictive covenants, including restrictions on our ability to enter into affiliate transactions, create liens on our assets, merge or consolidate without the prior consent of the lenders, sell, lease, transfer or otherwise dispose of the collateral securing the facility other than for market value on an arm's length basis and in compliance with the terms of the facility, incur additional indebtedness or make investments.

In addition, we may only pay dividends or make other distributions in respect of our capital stock under the $1.35 billion secured term loan facility in an amount equal to up to 50% of our net income of each previous financial year, provided in each case that we maintain minimum liquidity in an aggregate amount of not less of $200.0 million in cash and cash equivalents and restricted cash and maintain such level for the next 12 months following the date of the dividend payment.

The $1.35 billion secured term loan facility also contains customary events of default, including non-payment of principal or interest, breach of covenants or material representations and bankruptcy and imposes insurance requirements and restrictions on the employment of the mortgaged drillships. In addition, the facility contains a cross-default provision that is triggered, among other things, when any of our other financial indebtedness in an amount equal to or in excess of $25.0 million is not paid when due or is declared to be or otherwise becomes due and payable prior to its specified maturity as a result of an event of default, pursuant to which our lenders may accelerate our indebtedness under the $1.35 billion secured term loan facility.

As of December 31, 2012, we had entered into three interest rate swap agreements to partly fix the interest rate payable on the principal amounts outstanding under the $1.35 billion secured term loan facility. See "—Swap Agreements" for a description of the interest rate swap agreements.

Two $562.5 million senior secured credit facilities, amended to $495.0 million each (the Deutsche Bank credit facilities)

On July 18, 2008, Drillship Kithira Owners Inc. and Drillship Skopelos Owners Inc., our wholly owned subsidiaries and the owners of our drillships, the Ocean Rig Poseidon and the Ocean Rig Mykonos, respectively, each entered into separate credit facility agreements with a syndicate of lenders, including Deutsche Bank AG, London Branch, in the amount of $562.5 million to partially finance the construction costs of the Ocean Rig Poseidon and the Ocean Rig Mykonos, including payment of financing fees, incidental drillship costs, commitment fees, loan interest, and a portion of the second yard installments. We refer to these credit facilities as the Deutsche Bank credit facilities. Both of the credit facilities as amended, bear interest at a rate that is in part fixed and in part based on LIBOR plus an applicable margin and are repayable in 18 semi-annual installments of $27.5 million through September 2020 or November 2020, as the case may be.

On April 27, 2011, we entered into an agreement with the lenders under the Deutsche Bank credit facilities to amend these credit facilities. As a result of this restructuring, (i) the maximum amount permitted to be drawn was reduced from $562.5 million to $495.0 million under each credit facility; (ii) in addition to the guarantee already provided by DryShips, we provided an unlimited recourse guarantee that includes certain financial covenants as further described below; and (iii) with respect to the credit facility for the financing of the Ocean Rig Poseidon, we were permitted to draw under the facility with respect to the Ocean Rig Poseidon based upon the employment of the drillship under its drilling contract with Petrobras Tanzania. On August 10, 2011, we amended the terms of the credit facility for the financing of the Ocean Rig Mykonos to allow for full drawdowns to finance the then remaining installment payments for this drillship based on the employment of the drillship under its drilling contract with Petrobras Brazil. The amendment also requires that the Ocean Rig Mykonos be re-employed under a contract acceptable to the lenders meeting certain minimum terms and dayrates at least six months, in lieu of 12 months, prior to the expiration of the contract with Petrobras Brazil. All other material terms of such credit facility were unchanged.

Each Deutsche Bank credit facility is secured by, among other things, a first priority mortgage on the relevant vessel and a reserve account pledge. In addition, we have pledged the shares of the following of our wholly owned subsidiaries as security under our Deutsche Bank credit facilities: Kithira Shareholders Inc., Drillship Kithira Owners Inc., Ocean Rig Poseidon Operations Inc., Skopelos Shareholders Inc., Drillship Skopelos Owners Inc., Ocean Rig Drilling Operations Cooperatief UA, Ocean Rig Drilling Operations B.V. and Drillships Investment Inc. Each credit facility contains a loan to value ratio requirement relating to the post-delivery market value of the relevant vessel.

We provided an unlimited recourse guarantee under the terms of the restructuring of these credit facility agreements described above, whereby we are required to comply with certain financial covenants requiring that we maintain (i) a minimum equity ratio; (ii) a minimum amount of working capital; (iii) a maximum leverage ratio; (iv) a minimum interest coverage ratio; and (v) a minimum amount of free cash.

These credit facility agreements are the subjects of guarantees by DryShips. On May 14, 2012, we and Drillship Kithira Owners Inc. and Drillship Skopelos Owners Inc. signed amendments with the lenders under the Deutsche Bank credit facilities to, among other things, remove the payment guarantee of DryShips, subject to reinstatement as discussed below, and remove the financial covenants for DryShips and the cross-default provision relating to DryShips's outstanding indebtedness for its drybulk carrier and tanker fleet. As a result of the amendments, a default by DryShips under one of its loan agreements for its drybulk carrier and tanker fleet will not result in a cross-default under the Deutsche Bank credit facilities that would provide the lenders thereunder with the right to accelerate our outstanding debt. In addition, the amendments removed the automatic prepayment mechanism under the Deutsche Bank credit facilities. Also, by the end of September 2014, we are required to maintain an additional $57.0 million in the aggregate in the debt service reserve relating to the facilities. Furthermore, under the amended Deutsche Bank credit facilities, we are permitted to pay dividends, make distributions and effect redemptions or returns of share capital in an amount of up to 50% of net income, provided we maintain minimum liquidity in an aggregate amount of not less than $200.0 million in cash and cash equivalents and restricted cash and provide evidence to the lenders through cash flow forecasts that we will maintain such level for the next 12 months following the date of the dividend, distribution or redemption or return of share capital. The borrowers under the amended Deutsche Bank credit facilities are prohibited from paying dividends or making distributions to us or effecting redemptions, repayments or reductions of share capital, except following earnings deposit dates and unless all relevant primary transfers have been made, the borrowers maintain certain minimum balances in the debt service reserve accounts and no default has occurred, is continuing or will result from the payment. Notwithstanding the foregoing, in the case of the facility for the Ocean Rig Mykonos, the borrower may pay dividends to us upon earnings deposit dates in connection with (i) rebates of Brazilian import taxes incurred prior to May 14, 2012, (ii) the repayment of loans made by us to the borrower in respect of certain capital expenditures and operating expenses incurred prior to May 14, 2012; and (iii) any amounts paid by us following May 14, 2012 in respect of certain capital expenditures and operating expenses in excess of certain budgeted amounts, provided in each case all relevant primary transfers have been made. In addition, under the facility for the Ocean Rig Poseidon, Ocean Rig Poseidon Operations Inc., the borrower, is also prohibited from paying dividends or making distributions to us or effecting redemptions, repayments or reductions of share capital other than out of funds released from the bareboat charter proceeds account during the term of the bareboat charter in respect of the contract with Petrobras Tanzania for the Ocean Rig Poseidon.

Under the terms of the amended Deutsche Bank credit facilities, in the event of a breach by us of any of the financial covenants contained in our guarantees under the Deutsche Bank credit facilities, the unconditional and irrevocable payment guarantees of DryShips will be reinstated, pursuant to which DryShips will be obligated to pay, upon demand by the lenders, any amount outstanding under the credit facilities upon a failure by us to pay such amount. In addition, DryShips will be required to indemnify the lenders in respect of any losses they incur in respect of any amounts due under the loans that are not recoverable from DryShips under the guarantees and that we fail to pay. The amount payable by DryShips under the guarantees will be limited to $214.0 million with respect to the facility for the Ocean Rig Poseidon and $255.0 million with respect to the facility for the Ocean Rig Mykonos, in each case plus any other amounts that become payable in connection with the payment of such amount. The guarantees will not include any financial covenants applicable to DryShips or cross-default provisions in relation to DryShips's indebtedness for its drybulk carrier and tanker fleet. If these guarantees were to be reinstated, and subsequently were to become invalid or unenforceable for any reason, we would potentially be required to prepay the facilities.

The loan agreements contain customary restrictive covenants, including limitations on affiliate transactions, the creation of liens on assets and restrictions on the sale, transfer or disposal of the vessels, and events of default, including non-payment of principal or interest, minimum insurance requirements, breach of covenants or material misrepresentations, bankruptcy, and change of control and impose restrictions on the payments of dividends and employment of the vessels.

We have entered into four interest rate swap agreements to fix the interest rate payable on the principal amounts outstanding under the Deutsche Bank credit facilities. See "—Swap Agreements" for a description of the interest rate swap agreements.

As of December 31, 2012 and 2011, the outstanding balance under the Deutsche Bank credit facilities was $907.5 million and $990.0 million, respectively.

$800.0 million senior secured term loan agreement

On April 15, 2011, our wholly owned subsidiary, Drillships Holdings Inc., entered into a $800.0 million senior secured term loan agreement with Nordea Bank as agent and a syndicate of lenders to fund a portion of the construction of the Ocean Rig Corcovado and the Ocean Rig Olympia. The $800.0 million senior secured term loan agreement consists of four term loans, which were all fully drawn during April 2011. Amounts outstanding under the $800.0 million senior secured term loan agreement bear interest at LIBOR plus a margin and the loan is repayable in 20 quarterly installments plus a balloon payment of $483.3 million payable together with the last installment payment.

The $800.0 million senior secured term loan agreement is secured by, among other things, first priority (i) mortgages over the Ocean Rig Corcovado and the Ocean Rig Olympia; (ii) assignments of earnings; (iii) assignments of earnings accounts; (iv) assignments of minimum reserve cash accounts; (v) assignments of insurances; and (vi) pledges of the shares of our wholly owned subsidiaries, Drillships Holdings Inc., Drillship Hydra Shareholders Inc., Drillship Hydra Owners Inc., Drillship Paros Shareholders Inc., Drillship Paros Owners Inc. and Ocean Rig Corcovado Greenland Operations Inc.

Under the $800.0 million senior secured term loan agreement, we and certain of our subsidiaries, as guarantors, are subject to certain financial covenants requiring among other things, the maintenance of (i) a minimum amount of free cash; (ii) a leverage ratio not to exceed specified levels; (iii) a minimum interest coverage ratio; (iv) a minimum current ratio; and (v) a minimum equity ratio. In addition, the aggregate market value of the Ocean Rig Corcovado and the Ocean Rig Olympia must be greater than 140% of the total borrowings outstanding under the senior secured term loan.

On May 9, 2012, we and Drillships Holdings Inc. signed an amendment under the $800.0 million secured term loan agreement to, among other things, terminate the guarantee by DryShips and remove the related covenants and remove the cross-acceleration provisions relating to DryShips's indebtedness for its drybulk carrier and tanker fleet and our indebtedness under our other credit facilities. As a result of the amendment, a default by DryShips under one of its loan agreements for its drybulk carrier and tanker fleet or a default by us under one of our other credit facilities and the acceleration of the related debt will not result in a cross-default under our $800.0 million secured term loan agreement that would provide our lenders with the right to accelerate the outstanding debt under the loan agreement. In addition, under the terms of the loan agreement, as amended, (i) we are permitted to buyback our common shares; (ii) Drillships Holdings Inc. is permitted to pay dividends to us as its shareholder; and (iii) we are permitted to pay dividends to our shareholders of up to 50% of our net income of each previous financial year, provided in each case that we maintain minimum liquidity in an aggregate amount of not less than $200.0 million in cash and cash equivalents and restricted cash and maintain such level for the next 12 months following the date of the dividend payment. The amendments also provide for a reduction in the amount of minimum free cash required to be maintained by Drillships Holdings Inc. from $75.0 million to $50.0 million. Under the agreement, we are required to maintain minimum free cash of $100.0 million.

Furthermore, pursuant to the terms of the $800.0 million senior secured term loan agreement, if any person or group (other than George Economou and DryShips) acquires beneficial ownership of more than 50% of our equity, or, if George Economou and DryShips fails to hold a 15% aggregate ordinary voting power and economic interest in us, then all outstanding amounts under the $800.0 million senior secured term loan agreement are required to be prepaid within 60 days.

The $800.0 million senior secured term loan agreement contains other customary restrictive covenants, including limitations on affiliate transactions, the creation of liens on assets and restrictions on the sale, transfer or disposal of the vessels, and events of default, including non-payment of principal or interest, breach of covenants or material representations, bankruptcy and imposes insurance requirements and restrictions on the employment of the vessels.

We have entered into two interest rate swap agreements to fix the interest rate payable on the principal amounts outstanding under the $800.0 million senior secured term loan agreement. See "—Swap Agreements" for a description of the interest rate swap agreements.

As of December 31, 2012 and 2011, the outstanding balance under this loan was $700.0 million and $766.7 million, respectively.

9.5% senior unsecured notes due 2016

On April 27, 2011, we completed the issuance of $500.0 million aggregate principal amount of our 9.5% senior unsecured notes due 2016 in the 2011 Unsecured Bond Offering made to both non-U.S. persons in Norway in reliance on Regulation S under the Securities Act and to qualified institutional buyers in the United States in reliance on Rule 144A under the Securities Act. We received net proceeds of the 2011 Unsecured Bond Offering of approximately $487.5 million, which was used to finance a portion of the remaining payments under our newbuilding program and for general corporate purposes. DryShips, our parent company, purchased $75.0 million of our 9.5% senior unsecured notes due 2016 from a third party on May 18, 2011.

Under the terms of the bond agreement, dated April 14, 2011, we are required to pay interest on the unsecured notes at a rate of 9.5% per annum. We are also required to make interest payments on the unsecured notes semi-annually in arrears on October 27 and April 27 of each year, until the final maturity on April 27, 2016. The unsecured notes are not guaranteed by any of our subsidiaries. The unsecured notes are our unsecured obligations and rank senior in right of payment to any of our future subordinated indebtedness and equally in right of payment to all of our existing and future unsecured senior indebtedness. We may redeem some or all of the unsecured notes as follows: (i) at any time and from time to time from April 27, 2014 to April 26, 2015, at a redemption price equal to 104.5% of the aggregate principal amount, plus accrued and unpaid interest to the date of redemption; or (ii) at any time and from time to time from April 27, 2015 at a redemption price equal to 102.5% of the aggregate principal amount, plus accrued and unpaid interest to the date of redemption. Upon a change of control, which occurs if 50% or more of our shares are acquired by any person or group other than DryShips or its affiliates, the noteholders will have an option to require us to purchase all outstanding notes at a redemption price of 100% of the principal amount thereof plus accrued and unpaid interest to the date of purchase.

Subject to a number of limitations and exceptions, the bond agreement governing the unsecured notes contains covenants limiting, among other things, our ability to: (i) create liens; or (ii) merge, or consolidate or transfer, sell or lease all or substantially all of our assets. Furthermore, the bond agreement contains financial covenants requiring us, among other things, to ensure that we maintain: (i) a consolidated equity ratio of minimum 35%; (ii) free cash of minimum $50.0 million; (iii) a current ratio of minimum 1-to-1; and (iv) an interest coverage ratio of 2.5x calculated on a 12 month rolling basis.

In connection with the issuance, we agreed to apply to list the unsecured notes on a securities exchange or other regulated market by December 1, 2011. The unsecured notes were approved for trading on the Oslo ABM, which is maintained by the Oslo Bors ASA, on October 10, 2011. We have obtained a credit rating on our Company and the unsecured notes in compliance with the bond agreement. If we had failed to obtain the required credit ratings, the interest rate on the unsecured notes would have increased by 0.25% annually.

Repaid Debt Agreements

$1.04 billion senior secured credit facility

On September 17, 2008, our wholly owned subsidiaries, Ocean Rig ASA and Ocean Rig Norway AS, entered into a revolving credit and term loan facility with a syndicate of lenders that was amended and restated on November 19, 2009, to, among other things, add Drill Rigs Holdings as a borrower. This credit facility was in the aggregate amount of approximately $1.04 billion and consisted of a guarantee facility, which provided us with a letter of credit of up to $20.0 million that was drawn, three revolving credit facilities in the amounts of $350.0 million, $250.0 million and $20.0 million, respectively, and a term loan in the amount of up to $400.0 million. Amounts outstanding under the $1.04 billion credit facility bore interest at LIBOR plus a margin and the loan was repayable in 20 quarterly installments plus a balloon payment of $400.0 million payable together with the last installment, on September 17, 2013. This facility was repaid in full with a portion of the net proceeds of our 2012 Secured Bond Offering. As of December 31, 2011, the outstanding balance under this loan agreement was $522.5 million.

Drill Rigs Holdings had entered into three interest rate swap agreements to fix the interest rate on the principal amounts outstanding under this loan agreement, which were novated to us in connection with the closing of the 2012 Secured Bond Offering. See "—Swap Agreements" for a description of these interest rate swap agreements.

Cash Flows

Year Ended December 31, 2012 Compared to Year Ended December 31, 2011

Our cash and cash equivalents increased to $317.4 million as of December 31, 2012, compared to $250.9 million as of December 31, 2011, primarily due to cash provided by financing and operating activities partly offset by cash used in investing activities. Our working capital surplus was $91.5 million as of December 31, 2012, compared to a $68.9 million working capital surplus as of December 31, 2011.

Net Cash Provided by Operating Activities

Net cash provided by operating activities was $278.3 million for the year ended December 31, 2012. In determining net cash provided by operating activities for the year ended December 31, 2012, net income was adjusted for the effects of certain non-cash items, including $224.5 million of depreciation and amortization, $12.9 million of amortization and the write-off of deferred financing costs. Moreover, for the year ended December 31, 2012, net income was also adjusted for the effects of non-cash items, such as the gain in the change in fair value of derivatives of $16.1 million, amortization of discontinued cash flow hedges of $22.9 million, amortization of stock based compensation of $0.6 million and other non-cash items of $17.0 million. Net cash provided by operating activities was $270.7 million for the year ended December 31, 2011.

Net Cash Used in Investing Activities

Net cash used in investing activities was $320.5 million for the year ended December 31, 2012, compared to $1.6 billion for the year ended December 31, 2011. We made shipyard payments and project capital expenditures of approximately $310.1 million for the year ended December 31, 2012, compared to $1.9 billion for advances for drillships under construction and other capital expenditures for the year ended December 31, 2012. The increase in restricted cash was $10.6 million during the year ended December 31, 2012, compared to a decrease of $385.0 million in the corresponding period of 2011.

Net Cash Provided by Financing Activities

Net cash provided by financing activities was $108.7 million for the year ended December 31, 2012, consisting of $800.0 million in gross proceeds from the issuance of our 6.50% senior secured notes due 2017 in September 2012, which was largely offset by repayments of credit facilities amounting to an aggregate of $671.7 million. This compares to net cash provided by financing activities of $1.4 billion for the year ended December 31, 2011, consisting of $2.4 billion in gross proceeds from new long-term debt, which was largely offset by repayments of credit facilities amounting to an aggregate of $926.7 million.

Year Ended December 31, 2011 Compared to Year Ended December 31, 2010

Our cash and cash equivalents increased to $250.9 million as of December 31, 2011, compared to $95.7 million as of December 31, 2010, primarily due to cash provided by new financing and operating activities partly offset by cash used in investing activities. Our working capital surplus was $68.9 million as of December 31, 2011, compared to a $4.1 million working capital surplus as of December 31, 2010.

Net Cash Provided by Operating Activities

Net cash provided by operating activities was $270.7 million for the year ended December 31, 2011. In determining net cash provided by operating activities for the year ended December 31, 2011, net income was adjusted for the effects of certain non-cash items, including $162.5 million of depreciation and amortization, $17.8 million of amortization and the write-off of deferred financing costs. Moreover for the year ended December 31, 2011, net income was also adjusted for the effects of non-cash items, such as the gain in the change in fair value of derivatives of $15.1 million, amortization of discontinued cash flow hedges of $9.8 million, amortization of below market value acquired drilling contracts of $1.2 million and $4.3 million interest income on restricted cash. Net cash provided by operating activities was $221.8 million for the year ended December 31, 2010.

Net Cash Used in Investing Activities

Net cash used in investing activities was $1.6 billion for the year ended December 31, 2011, compared to $1.4 billion for the year ended December 31, 2010. We made shipyard payments and project capital expenditures of approximately $1.9 billion for the year ended December 31, 2011, compared to $711.9 million for advances for drillships under construction and other capital expenditures for the year ended December 31, 2010. The decrease in restricted cash was $385.0 million during the year ended December 31, 2011, reflecting primarily repayment of the $300.0 million short-term credit facility that was classified as restricted cash as of December 31, 2010, compared to an increase of $335.9 million in the corresponding period of 2010.

Net Cash Provided by Financing Activities

Net cash provided by financing activities was $1.4 billion for the year ended December 31, 2011, consisting of $2.4 billion in net proceeds from new long-term debt, which was largely offset by repayments of credit facilities amounting to an aggregate of $926.7 million. This compares to net cash provided by financing activities of $1.08 billion for the year ended December 31, 2010, consisting mainly of stockholders contribution to fund investments of $540.3 million, net proceeds from the private offering of $488.3 million, proceeds from bank debt of $308.2 million and the repayment of bank debt of $247.7 million.

Swap Agreements

As of December 31, 2012, we had twelve interest rate swap and cap and floor agreements outstanding, with a notional amount of $2.8 billion, maturing from September 2013 through November 2017. These agreements were entered into in order to economically hedge our exposure to interest rate fluctuations with respect to our borrowings. As of December 31, 2012, the aggregate fair value the above agreements was a net liability of $76.7 million. This fair value equates to the amount that would be paid by us if the agreements were cancelled at the reporting date, taking into account current interest rates and our creditworthiness.

As of December 31, 2011, we had seven interest rate swap and cap and floor agreements outstanding, with a notional amount of $1.0 billion, maturing from September 2013 through November 2017. As of December 31, 2011, the fair value of the above agreements was a liability of $92.8 million.

As of January 1, 2011, we discontinued hedge accounting and, as such, changes in the fair values of the agreements entered into as of December 31, 2012 and December 31, 2011 are included in the accompanying consolidated statement of operations.

As of December 31, 2010, we had outstanding 11 interest rate swap and cap and floor agreements, with a notional amount of $908.0 million, maturing from September 2011 through November 2017. These agreements were entered into in order to economically hedge our exposure to interest rate fluctuations with respect to our borrowings. As of December 31, 2010, eight of these agreements did not qualify for hedge accounting and, as such, changes in their fair values are included in the accompanying consolidated statement of operations. As of December 31, 2010, three agreements qualified for and were designated for hedge accounting and, as such, changes in their fair values are included in other comprehensive loss. The fair value of these agreements equates to the amount that would be paid by us if the agreements were cancelled at the reporting date, taking into account current interest rates and our creditworthiness.

As of December 31, 2011 and 2012, security deposits of $33,100 and $8,000, respectively were provided as security by the Company. The Company has deposited also cash collateral of $6,000 that is classified as current restricted cash. These amounts are expected to be released upon the delivery of the Ocean Rig Mylos, the Ocean Rig Skyros and the Ocean Rig Athena.

See "Item 11. Quantitative and Qualitative Disclosures About Market Risk."

Currency Forward Sale Exchange Contracts

As of December 31, 2012 and December 31, 2011, we had no outstanding currency forward sale exchange contracts. The change in fair value of forward contracts during the year ended December 31, 2011 amounted to a loss of $1.5 million and is included as Other, net in our consolidated statement of operations. See Note 10 to our consolidated financial statements included elsewhere in this annual report.

As of December 31, 2010, we had currency forward sale exchange contracts for the future sales of U.S. Dollars at fixed rates of $28.0 million outstanding with a fair market value of $1.5 million recorded in "Financial instruments" in our consolidated balance sheet. For the relevant period, we did not designate currency forward sale exchange contracts as hedges under U.S. GAAP, and realized gains are included as General and administrative expenses and unrealized gains are included as Other, net in our consolidated statement of operations. See Note 10 to our consolidated financial statements included elsewhere in this annual report.

See "Item 11. Quantitative and Qualitative Disclosures About Market Risk."

Supplemental Information – Drill Rigs Holdings

Drill Rigs Holdings, the issuer of our Senior Secured Notes, or the Issuer, is a corporation incorporated under the laws of the Republic of the Marshall Islands on October 10, 2008. The Issuer is a wholly owned subsidiary of the Company. Ocean Rig 1 Inc. and Ocean Rig 2 Inc., corporations incorporated under the laws of the Marshall Islands on October 10, 2008, and wholly owned subsidiaries of the Issuer, each separately own and operate our modern, fifth generation ultra-deepwater semi-submersible offshore drilling rigs, the Leiv Eiriksson and the Eirik Raude, respectively. The Senior Secured Notes are secured by, among other things, first priority mortgages on the Leiv Eiriksson and the Eirik Raude. Ocean Rig 1 Inc. and Ocean Rig 2 Inc., along with other existing and future subsidiaries of the Issuer that hold or will hold the Leiv Eiriksson or the Eirik Raude, or certain assets related to such drilling rigs, or that are or become a party to a drilling contract for the employment of the Leiv Eiriksson or the Eirik Raude, or collectively, the Issuer Subsidiary Guarantors, and Ocean Rig UDW Inc. are guarantors of our Senior Secured Notes. The address for the Issuer and Issuer Subsidiary Guarantors' principal place of business is c/o Ocean Rig UDW Inc., 10 Skopa Street, Tribune House, 2nd Floor, Office 202, CY 1075, Nicosia.

The following is additional information about the Issuer and Issuer Subsidiary Guarantors, all of which are wholly owned subsidiaries of the Issuer, as of December 31, 2012.

(a)

Drill Rigs Holdings Inc. is a private limited company organized under the laws of theMarshall Islands. It is registered under registration number 32563 and the address of itsregistered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro,Marshall Islands MH 96960.

(b)

Ocean Rig 1 Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 32564 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

(c)

Ocean Rig 2 Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 32566 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

(d)

Ocean Rig 1 Shareholders Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 32565 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

(e)

Ocean Rig 2 Shareholders Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 32567 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

(f)

Ocean Rig 1 Greenland Operations Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 42634 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

(g)

Ocean Rig Falkland Operations Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 49548 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

(h)

Drill Rigs Operations Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 49395 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

(i)

Ocean Rig EG Operations Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 53660 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

(j)

Ocean Rig Norway Operations Inc. is a private limited company organized under the laws of Marshall Islands. It is registered under registration number 53753 and the address of its registered office is at Trust Company Complex, Ajeltake Road, Ajeltake Island, Majuro, Marshall Islands MH 96960.

Selected Historical Consolidated Financial Information and Other Data:

The following table sets forth certain financial and other data of Drill Rigs Holdings, our wholly-owned subsidiary and the issuer of our Senior Secured Notes, and its operating subsidiaries, each an Issuer Subsidiary Guarantor of the Senior Secured Notes, at the dates and for the periods indicated, which is derived from unaudited financial statements of Drill Rigs Holdings and its operating subsidiaries on a consolidated basis and was prepared by us for use in connection with certain reporting requirements set forth under the indenture governing the Senior Secured Notes.



	Year Ended
(U.S. Dollars in thousands)	2011			2012
Total revenue		333,889			313,479
EBITDA(1)		238,073			34,160
Total assets		1,342,648			1,271,829
Total debt, net of financing fees		(519,731	)		(781,001	)
Shareholders' equity		(730,198	)		(337,086	)
Total cash and cash equivalents		41,669			62,429
Capital expenditures (2)		(20,065	)		(27,908	)

(1)

EBITDA represents net income before interest, taxes, depreciation and amortization. EBITDA is a non-U.S. GAAP measure and does not represent and should not be considered as an alternative to net income or cash flow from operations, as determined by U.S. GAAP or other U.S. GAAP measures, and our calculation of EBITDA may not be comparable to that reported by other companies. EBITDA is included herein because it is a basis upon which we measure our operations and efficiency. EBITDA is also used by various of our lenders as a measure of our compliance with certain loan covenants and because we believe that it presents useful information to investors regarding a company's ability to service and/or incur indebtedness.

(2)	Capital expenditures represent fixed assets improvements excluding items expensed for the Leiv Eiriksson and the Eirik Raude class surveys incurred during the fiscal years ended December 31, 2011 and 2012, amounting to $15.3 million and $65.5 million, respectively.

EBITDA reconciliation

EBITDA represents net income before interest, taxes, depreciation and amortization and. EBITDA does not represent and should not be considered as an alternative to net income or cash flow from operations, as determined by US GAAP and our calculation of EBITDA may not be comparable to that reported by other companies. EBITDA is included herein because it is a basis upon which Drill Rigs Holdings measures its operations and efficiency. EBITDA is also presented herein because Drill Rigs Holdings believes that it presents useful information to investors regarding a company's ability to service and/or incur indebtedness.

	Year Ended
(U.S. Dollars in thousands)	2011			2012
EBITDA reconciliation
Net income		132,904			(75,875	)
Interest and finance costs		42,888			36,588
Interest income		(17,337	)		(6,137	)
Depreciation		75,212			73,322
Income taxes		4,406			6,262

EBITDA		238,073			34,160

Additional Unaudited Financial Information

The below information was prepared by us for use in connection with certain reporting requirements set forth under the indenture governing the Senior Secured Notes.

For the fiscal year ended December 31, 2012, EBITDA of Ocean Rig UDW Inc. and its consolidated subsidiaries, or the Group, attributable to the Issuer, the Issuer Subsidiary Guarantors and the subsidiaries of Ocean Rig UDW Inc. that are not guarantors of the Senior Secured Notes, or the Non-guarantors, was $-14.1million (or -5.6%), $48.3million (or 19.2%) and $217.8million (or 86.4 %), respectively.

As of December 31, 2012, the net assets of the Group attributable to the Issuer, the Issuer Subsidiary Guarantors and the Non-guarantors were $ -858.2 million (or -29.5%,) $1,195.3 million (or 41.1%) and $2,571.4 million (or 88.4%), respectively.

For the fiscal year ended December 31, 2012, EBITDA of the Group attributable to our Issuer Subsidiary Guarantors, Ocean Rig 1 Inc., the owner of the Leiv Eiriksson, and Ocean Rig 2 Inc., the owner of the Eirik Raude, accounted for $58.5 million (or 23.2%) and $-10.2 million (or -4.1%), respectively; and the net assets of the Group attributable to them as of that date were $596.2 million (or 20.5%) and $591.5 million (or 20.3%), respectively.

	For the Year Ended December 31, 2012
(U.S. Dollars in thousands)	Issuer			Issuer Subs Guarantor			Non-guarantors			Ocean Rig 1 Inc./ Leiv Eiriksson			Ocean Rig 2 Inc./ Eirik Raude
EBITDA reconciliation
Net income		(48,535	)		(27,340	)		(56,461	)		25,316			(51,212	)
Depreciation		109			73,213			151,157			34,697			37,073
Interest and finance costs		36,555			33			79,840			15			19
Interest income		(2,256	)		(3,881	)		5,583			(529	)		(3,352	)
Income Taxes		—			6,262			37,695			(989	)		7,251

EBITDA(1)		(14,127	)		48,287			217,814			58,510			(10,221	)

(1) EBITDA represents net income before interest, taxes, depreciation and amortization. EBITDA is a non-U.S. GAAP measure and does not represent and should not be considered as an alternative to net income or cash flow from operations, as determined by U.S. GAAP or other U.S. GAAP measures, and our calculation of EBITDA may not be comparable to that reported by other companies. EBITDA is included herein because it is a basis upon which we measure our operations and efficiency.

High Composition of Non-Guarantor Companies

As non-guarantor companies may represent in excess of 25% of the EBITDA or net assets of the group's audited consolidated financial statements, the consolidated financial information may be of limited use in assessing the financial position of the guarantors of the Senior Secured Notes.

C. Research and Development, Patents and Licenses, etc.

Not applicable.

D. Trend Information

E. Off-balance Sheet Arrangements

We do not have any off-balance sheet arrangements.

F. Tabular disclosure of contractual obligations

The following table sets forth our contractual obligations and their maturity dates as of December 31, 2012:

Obligations	Total		Less than 1 year		1-3 years		3-5 years		More than 5 years
(U.S. Dollars in thousands)

Drillships under construction (1)		1,566,876		1,179,776		387,100		-		-
Retirement Plan Benefits (2)		2,955		93		270		401		2,191
Operating leases (3)		5,014		2,774		1,818		422		-
Loan payments (4)		2,907,500		176,667		353,333		2,020,000		357,500
Interest payments (5)		747,585		163,342		339,375		201,949		42,919

Total		5,229,930		1,522,652		1,081,896		2,222,772		402,610

____________________________

(1)	The figure includes contracted purchase obligations only.

(2)

We have three defined benefit plans for our employees managed and funded through Norwegian life insurance companies at December 31, 2012. The pension plans covered 44 employees by December 31, 2012. Pension liabilities and pension costs are calculated based on the actuarial cost method as determined by an independent third party actuary.

(3)	The Company has operating leases mostly relating to premises the most significant being its offices in Stavanger, Rio de Janeiro, Jersey and Aberdeen.

(4)	Includes $500 million in aggregate principal amount of 9.5% senior unsecured notes and $800 million in aggregate principal amount of 6.5% senior secured notes.

(5)	Based on assumed interest rates ranging from 4.14% to 9.5%.

Recent Accounting Pronouncements:

There are no recent accounting pronouncements issued in 2012, whose adoption would have a material impact on the Company's consolidated financial statements in the current year or that are expected to have a material impact on the Company's consolidated financial statements in future years.

G. Safe Harbor

See the section entitled "Forward-looking Statements" at the beginning of this annual report.

Item 6. Directors, Senior Management and Employees

A. Directors and senior management

Set forth below are the names, ages and positions of our directors and executive officers and the principal officers of certain of our operating subsidiaries. Members of our board of directors are elected annually on a staggered basis. Each director elected holds office for a three-year term and until his successor shall have been duly elected and qualified, except in the event of his death, resignation, removal, or the earlier termination of his term of office. Officers are appointed from time to time by our board of directors, or our relevant subsidiary, as applicable, and hold office until a successor is appointed.

Directors and executive officers of Ocean Rig UDW Inc.(1)
Name	Age	Position
George Economou	60	Chairman of the Board, President, Chief Executive Officer and Class A Director
Michael Gregos	41	Class B Director
Trygve Arnesen	55	Class C Director
Savvas D. Georghiades	62	Class C Director
Prokopios (Akis) Tsirigakis	58	Class B Director
Anthony Kandylidis	35	Executive Vice President
Gilles Bocabarteille	45	Senior Vice President of Technical and Engineering
Mark Bessell(2)	48	Senior Vice President of Operations
Principal officers of Ocean Rig UDW Inc.'s operating subsidiaries(3)
Name	Age	Position
Jan Rune Steinsland(4)	53	Chief Financial Officer

(1) Effective October 2, 2012, Pankaj Khanna resigned from his position as Chief Marketing Officer of Ocean Rig UDW Inc., which he had held since January 1, 2012.

(2) Effective March 31, 2013, Mark Bessell will resign from his position as Senior Vice President of Operations of Ocean Rig UDW Inc.

(3) Effective October 2, 2012, Frank Tollefsen resigned from his position as Chief Operating Officer and Deputy Chief Executive Officer of Ocean Rig AS, our wholly-owned subsidiary, which he had held since February 2011.

(4) Effective March 31, 2013, Jan Rune Steinsland will resign from his position as Chief Financial Officer of Ocean Rig AS, our wholly-owned subsidiary.

The business address of each of our directors and executive officers is 10 Skopa Street, Tribune House, 2nd Floor, Office 202, CY 1075, Nicosia, Cyprus.

Biographical information with respect to the above individuals is set forth below.

George Economou was appointed as our President and Chief Executive Officer on September 2, 2010, and Chairman and director in December 2010. Mr. Economou has over 25 years of experience in the maritime industry. He has served as Chairman, President and Chief Executive Officer of DryShips Inc. since January 2005. He successfully took DryShips public in February 2005, on NASDAQ under the trading symbol "DRYS". Mr. Economou has overseen the growth of DryShips into one of the largest US-listed dry bulk companies in fleet size and revenue and one of the largest Panamax owners in the world. Mr. Economou has also served as a director of Danaos Corporation and a director and President of AllShips Inc. since 2010. Mr. Economou began his career in 1976 when he commenced working as a Superintendent Engineer in Thenamaris Ship Management in Greece. From 1981-1986 he held the position of General Manager of Oceania Maritime Agency in New York. Between 1986 and 1991 he invested and participated in the formation of numerous individual shipping companies and in 1991 he founded Cardiff Marine Inc., Group of Companies. Mr. Economou is a member of ABS Council, Intertanko Hellenic Shipping Forum, and Lloyds Register Hellenic Advisory Committee. Mr. Economou is a graduate of the Massachusetts Institute of Technology and holds both a Bachelor of Science and a Master of Science degree in Naval Architecture and Marine Engineering and a Master of Science in Shipping and Shipbuilding Management.

Michael Gregos was appointed to our board of directors in December 2010. Since March 2009, Mr. Gregos has served as the Project Manager for Dynacom Tankers Management Ltd., a position he also served in from 2001 to September 2007. From September 2007 to February 2009, Mr. Gregos was employed at OceanFreight Inc. and served as the Chief Operating Officer of OceanFreight Inc. from January 2008 to February 2009. Prior to that period, he worked for a shipping concern based in Athens and New York for five years and the Corporate Finance arm of a Greek bank for one year. He is a graduate of Queen Mary University in London and holds an M.Sc. in Shipping, Trade and Finance from City University.

Trygve Arnesen was appointed to our board of directors in December 2010. Mr. Arnesen is a director for Aftermarket Eastern Region with FMC Technologies, a position he has held since August 2010. Mr. Arnesen holds an M.Sc. in petroleum engineering and applied geophysics from the Norwegian University of Science and Technology from 1980. He has worked in the drilling and oil service industry since 1982, and has held a broad range of positions with various companies including Wilhelmsen (1982-1984), Morco&Ross (1984-1985), Norcem / Aker Drilling (1985-1989), Saga (1989), Transocean / Procon / Prosafe (1990-1992 and 1994-2005), Shell (1992-1994), and Odfjell (2005-2006). From 2006 to 2008, Mr. Arnesen was the Chief Executive Officer of Ocean Rig ASA, our predecessor, and he worked as Chief Executive Officer for Norwind from 2008 until 2010.

Savvas Georghiades was appointed to our board of directors in December 2010. Mr. Georghiades has been a practicing lawyer in Cyprus since 1976. He is a graduate of the Aristotle University in Thessaloniki, Greece.

Prokopios (Akis) Tsirigakis was appointed to serve on our board of directors effective September 12, 2011. Mr. Tsirigakis serves as Chairman of the Board of Directors, President and Co-Chief Executive Officer of Nautilus Marine Acquisition Corp., a blank check company formed for the purpose of acquiring one or more operating businesses or assets. In November 2007 he founded, and until February 2011 was the President and Chief Executive Officer of, Star Bulk Carriers Corp., a dry-bulk shipping company listed on the NASDAQ Stock Market (NASDAQ: SBLK). He also served as a director of Star Bulk Carriers Corp. from November 2007 to March 2012. From November 2005 until November 2007, Mr. Tsirigakis founded and served as Chairman of the Board, Chief Executive Officer and President of Star Maritime Acquisition Corp. (AMEX: SEA). Mr. Tsirigakis is experienced in ship ownership, ship management and new shipbuilding projects. Mr. Tsirigakis formerly served on the board of directors of DryShips. Since November 2003, he served as Managing Director of Oceanbulk Maritime S.A., a dry cargo shipping company that has operated and managed vessels. From November 1998 until November 2007, Mr. Tsirigakis served as the Managing Director of Combine Marine Inc., a company which he founded and that is providing ship management services to third parties. From 1991 to 1998, Mr. Tsirigakis was the Vice-President and Technical Director of Konkar Shipping Agencies S.A. of Athens, after having served as Konkar's Technical Director from 1984 to 1991. From 1982 to 1984, Mr. Tsirigakis was the Technical Manager of Konkar's affiliate, Arkon Shipping Agencies Inc. of New York. He is a life-member of The Propeller Club of the United States, a member of the Technical Committee (CASTEC) of Intercargo, the International Association of Dry Cargo Shipowners, President of the Hellenic Technical Committee of RINA, the Italian Classification Society and member of the Technical Committees of various Classification Societies. Mr. Tsirigakis received his Masters and B.Sc. in Naval Architecture from The University of Michigan, Ann Arbor and has seagoing experience.

Anthony Kandylidis has served as our Executive Vice President since June 2012. Mr. Kandylidis started his career at OMI Corporation's commercial department. During his tenure at OMI Corporation, he gained significant experience in the tanker vessel business and held various positions with responsibilities spanning Sale and Purchase, Time Charters, FFA Trading, Corporate Finance and Strategic Planning. In the spring of 2006, Mr. Kandylidis returned to Greece where he provided consultancy services to companies affiliated with Mr. George Economou. In September of 2006, Mr. Kandylidis founded OceanFreight Inc. and he took OceanFreight Inc. public in April of 2007. In 2011 OceanFreight Inc. was absorbed by DryShips through a merger. Mr. Kandylidis graduated magna cum laude from Brown University and continued his studies at the Massachusetts Institute of Technology where he graduated with a Masters degree of Science in Ocean Systems Management. Mr. Kandylidis is the nephew of our Chairman, President and Chief Executive Officer and the Chairman, President and Chief Executive Officer of DryShips, Mr. George Economou, and the son of a director of DryShips.

Gilles Bocabarteille joined our company in August 2012 as Senior Vice President Technical and Engineering and has served as our Senior Vice President Operations and Technical since January 1, 2013. Prior to joining our company, Mr. Bocabarteille served as Vice President, Asset Management of Ensco plc, or Ensco, and, prior to its acquisition by Ensco, Pride International, Inc., or Pride International, from 2008 to 2012. Mr. Bocabarteille also served as Managing Director of Pride International from 2005 to 2008 in Brazil, Operations Manager, Rig Manager and Offshore Installation Manager of Pride International from 1999 to 2004 in Angola and Commissioning Manager of Pride International for the construction of the Pride Angola in Korea in 1999. Mr. Bocabarteille began his career with FORASOL in 1991, where he served as Country Manager, Venezuela from 1994 to 1996 and Offshore Operations Manager from 1996 to 1998. Mr. Bocabarteille received a Mechanical Engineering degree from Arts et Metiers "ENSAM" in France in 1991.

Mark Bessell has served as our Senior Vice President of Operations since April 2012. Mr. Bessell has 25 years of experience in oil and gas industry, holding various positions in the drilling contracting business. Mr. Bessell has held a diverse number of leadership positions in the North Sea, Houston, Paris, West Africa, Far East and the Mediterranean and Middle East regions. Prior to joining the Company, he spent 24 years with Transocean Ltd., where he served in various managerial roles, most recently as Managing Director, Mediterranean Division from September 2009 to March 2012. Mr. Bessell is a graduate of Montana College of Mineral Science and Technology with a B.Sc. in Petroleum Engineering.

Jan Rune Steinsland is the Chief Financial Officer of Ocean Rig AS and joined the Ocean Rig group of companies in 2006. Mr. Steinsland also serves on the board of directors of 42 of the companies in the Ocean Rig group and is the President and a director of the Issuer. Mr. Steinsland has 17 years of experience from various positions in the energy and drilling industry and eight years of experience in the finance and technology industries. From 2000 to 2006, Mr. Steinsland was Chief Financial Officer of the Oslo Børs-listed Acta Holding ASA. From 1988 to 2000, Mr. Steinsland held several management positions in Esso Norge AS/Exxon Company International, including Financial Analyst, Financial Reporting Manager, Vice President Accounting, Project Controller and Audit Advisor. Mr. Steinsland has a Master of Business Administration from the University of St. Gallen Switzerland and is a Certified European Financial Analyst (AFA) from The Norwegian Society of Financial Analysts/Norwegian School of Economics and Business Administration.

B. Compensation

The aggregate compensation paid by us to the members of our senior management was $4.06 million for the year ended December 31, 2012, consisting of $4.02 million in salary and bonus and $ 0.04 million in pension contribution and other benefits.

Our non-employee directors are each entitled to receive annual directors' fees of $20,000, such amount to be pro-rated for any portion of a full calendar year that a non-employee director is a member of our board of directors, plus reimbursement for actual expenses incurred while acting in their capacity as director. In addition, the chairmen of the committees of our board of directors receive annual fees of $10,000, such amount to be pro-rated for any portion of the full calendar year that the director is chairman of the committee, plus reimbursement for actual expenses incurred while acting in their capacity as chairman. We do not maintain a medical, dental, or retirement plan for our directors. Members of our senior management who also serve as directors do not receive additional compensation for their services as directors.

Our board of directors has adopted an equity incentive plan, pursuant to which officers, directors and employees of the Company, our subsidiaries and our affiliates and consultants and service providers to the Company, our subsidiaries and our affiliates are eligible to receive awards under the plan. See "—E. Share Ownership—2012 Equity Incentive Plan" below.

C. Board Practices

Our board of directors consists of the five directors named above. Each director elected holds office for a three-year term and until his successor shall have been duly elected and qualified, except in the event of his death, resignation, removal, or the earlier termination of his term of office. The term of office of each director is as follows: our Class A director, Mr. George Economou, serves for a term expiring at the 2014 annual general meeting of shareholders, our two Class B directors, Messrs. Michael Gregos and Prokopios (Akis) Tsirigakis, serve for a term expiring at the 2015 annual meeting of shareholders and our two Class C directors, Messrs. Trygve Arnesen and Savvas D. Georghiades, serve for a term expiring at the 2013 annual meeting of shareholders.

There are no service contracts between us or any of our subsidiaries and any of our directors providing for benefits upon termination of their employment or service.

Our board of directors has determined three of our directors to be independent under Rule 10A-3 of the Exchange Act and the rules of the NASDAQ Stock Market: Messrs. Gregos, Arnesen and Tsirigakis. Under the NASDAQ corporate governance rules, a director is not considered independent unless our board of directors affirmatively determines that the director has no direct or indirect material relationship with us or our affiliates that could reasonably be expected to interfere with the exercise of such director's independent judgment. In making this determination, our board of directors broadly considers all facts and circumstances it deems relevant from the standpoint of the director and from that of persons or organizations with which the director has an affiliation.

We have established an audit committee, a compensation committee and a nominating and corporate governance committee, in each case comprised of independent directors.

Our audit committee, among other things, reviews our external financial reporting, engages our external auditors and oversees our internal audit activities, procedures and the adequacy of our internal accounting controls. Messrs. Gregos, Arnesen and Tsirigakis serve as members of the audit committee. Mr. Tsirigakis serves as Chairman of the audit committee. The board of directors has determined that Mr. Tsirigakis qualifies as an "audit committee financial expert" as defined in Item 407 of Regulation S-K promulgated by the SEC and Form 20-F.

Our compensation committee is responsible for establishing directors and executive officers' compensation and benefits and reviewing and making recommendations to the board of directors regarding our compensation policies. Messrs. Gregos, Arnesen and Tsirigakis serve as members of the compensation committee. Mr. Gregos serves as Chairman of the compensation committee.

Our nominating and corporate governance committee is responsible for recommending to the board of directors nominees for director and directors for appointment to committees of the board of directors and advising the board of directors with regard to corporate governance practices. Shareholders may also nominate directors in accordance with procedures set forth in our second amended and restated bylaws. Messrs. Gregos, Arnesen and Tsirigakis serve as members of the nominating and corporate governance committee. Mr. Arnesen serves as Chairman of the nominating and corporate governance committee.

D. Employees

As of December 31, 2012, Ocean Rig UDW Inc. employed 10 individuals, including our Chief Executive Officer, Executive Vice President and Senior Vice President of Operations. As of December 31, 2012, the total number of employees employed by our wholly-owned management subsidiaries was approximately 1,374, of which approximately 244 were full-time crew engaged through third party crewing agencies. Of the total number of employees, approximately 144 were assigned to the Eirik Raude, approximately 154 were assigned to the Leiv Eiriksson, approximately 186 were assigned to the Ocean Rig Corcovado, approximately 205 were assigned to the Ocean Rig Olympia, approximately 202 were assigned to the Ocean Rig Poseidon and approximately 182 were assigned to the Ocean Rig Mykonos. In addition, the newbuild drillship project team, located in South Korea and Norway, employed 44 employees and 48 employees were employed in a resource pool, while the management and staff positions at the Stavanger office consisted of 139 employees. Furthermore, there were 67 employees based at our Aberdeen, Rio de Janeiro and Jersey offices and 5 employees based in other locations.

As of December 31, 2011, Ocean Rig UDW Inc. employed one individual, our Chief Executive Officer. As of December 31, 2011, our wholly-owned management subsidiaries employed approximately 1,305 employees, including shore-based support teams in Turkey and Ghana, of which approximately 337 were full-time crew engaged through third party crewing agencies. Of the total number of employees, approximately 162 were assigned to the Eirik Raude, approximately 139 were assigned to the Leiv Eiriksson, approximately 202 were assigned to the Ocean Rig Corcovado, approximately 200 were assigned to the Ocean Rig Olympia, approximately 214 were assigned to the Ocean Rig Poseidon and approximately 191 were assigned to the Ocean Rig Mykonos. In addition, the newbuild drillship project team, located in South Korea and Norway, employed 70 employees, while the management and staff positions at the Stavanger office consisted of 110 employees. Furthermore, there were 12 employees based at our Aberdeen office and five employees based in other locations.

As of December 31, 2010, our management subsidiaries employed approximately 564 employees, of which approximately 119 were full-time crew engaged through third party crewing agencies. Of the total number of employees, approximately 160 were assigned to the Eirik Raude, approximately 143 were assigned to the Leiv Eiriksson, approximately 88 were assigned to the Ocean Rig Corcovado and 49 were assigned to the Ocean Rig Olympia. These numbers include shore-based support teams in Turkey and Ghana. The newbuild drillship project team, located in Korea and Norway, employed 50 employees, while the management and staff positions at the Stavanger office consisted of 59 employees. In addition, there were four employees based at the London office and two employees based in other locations.

The increase of employees from December 31, 2010 to December 31, 2011 and 2012 is primarily due to the general growth of our business.

We did not experience any material work stoppages due to labor disagreements during 2012, 2011 or 2010.

Employment Agreements

Effective June 1, 2012, we entered into a consultancy agreement with Basset Holdings Inc., or Basset, a Marshall Islands entity beneficially owned by our Executive Vice President, Mr. Anthony Kandylidis, for the provision of the services of our Executive Vice President. The agreement has an initial term of five years and may be renewed or extended for one-year successive terms with the consent of both parties. Under the terms of the agreement, we are be obligated to pay an annual remuneration to Basset of Euro 0.9 million ($1.2 million based on the Euro/U.S. Dollar exchange rate as of December 31, 2012), plus a sign on bonus. Basset is also entitled to cash or equity-based bonuses to be awarded at our sole discretion. We may terminate the agreement for cause, as defined in the agreement, in which case Basset will not be entitled to further payments of any kind. Upon termination of the agreement by us without cause, or in the event the agreement is terminated within three months of a change of control, as defined in the agreement, we will be obligated to pay a lump sum amount. Basset may terminate the agreement without cause upon three months written notice. For the year ended December 31, 2012, the Company incurred costs of $2.5 million, including a sign on bonus of Euro 1.5 million ($1.8 million based on the Euro/U.S. Dollar exchange rate at the date that the transaction was recorded) related to this agreement.

Effective August 16, 2012, we entered into a consultancy agreement with Mr. Gilles Bocabarteille for his services as our Senior Vice President of Technical and Engineering. The agreement has an initial term of three years and may be renewed or extended for additional one-year periods upon mutual agreement of the parties. Under the agreement, Mr. Bocabarteille is entitled to a monthly base remuneration, plus equity or cash bonuses to be awarded at our sole discretion. In the event the agreement is terminated by us for cause, as defined in the agreement, or by Mr. Bocabarteille without cause, Mr. Bocabarteille will not be entitled to any further payments of any kind under the agreement. Upon termination of the agreement by us without cause, any cash or equity bonuses already granted to Bocabarteille shall vest immediately and we will be obligated to pay Mr. Bocabarteille a lump-sum amount.

Our wholly owned subsidiary, Ocean Rig ASA (which has since been reorganized into Drill Rigs Holdings), entered into an employment agreement, dated as of May 15, 2006, with Mr. Jan Rune Steinsland for his services as Chief Financial Officer, pursuant to which Mr. Steinsland receives a fixed annual salary and may receive a bonus through the management bonus plan. The agreement continues until terminated by either party on six-months' notice. In addition, Mr. Steinsland is entitled to participation in our pension scheme. As of December 1, 2008, Mr. Steinsland's employment contract was amended to transfer Mr. Steinsland's employment from Ocean Rig ASA to Ocean Rig AS pursuant to the same terms and conditions described above.

E. Share Ownership

With respect to the total amount of common shares owned by our officers and directors, individually and as a group, see "Item 7. Major Stockholders and Related Party Transactions—A. Major Shareholders."

2012 Equity Incentive Plan

On March 21, 2012, our board of directors adopted the Ocean Rig UDW Inc. 2012 Equity Incentive Plan, or the plan, the material terms of which are set forth below. Under the plan, officers, directors and employees of, and consultants and service providers to, us, our subsidiaries and our affiliates are eligible to participate. The plan provides for the award of stock options, stock appreciation rights, restricted stock, restricted stock units, phantom stock units, dividend equivalents, unrestricted stock, and other stock or cash-based awards.

Administration

The plan is administered by our compensation committee, or such other committee of our board of directors as may be designated by our board of directors. The plan administrator has the authority to, among other things, designate participants under the plan, determine the type or types of awards to be granted to a participant, determine the number of shares of common stock to be covered by awards, determine the terms and conditions applicable to awards and interpret and administer the plan.

Number of Shares of Common Stock

Subject to adjustment in the event of any distribution, recapitalization, split, merger, consolidation and the like, the number of shares of our common stock with respect to which awards may be granted under the plan is 2,000,000. Shares subject to an award that remain unissued upon the termination or cancellation of the award, restricted shares awarded under the plan that are forfeited, shares in respect of an award that are settled for cash without delivery of common stock, and shares that are tendered or withheld to satisfy the grant or exercise price or tax withholding obligation pursuant to an award under the plan, will again be available for grant under the plan. Common stock delivered under the plan consists of authorized but unissued shares or shares acquired by us in the open market, from us or from any other person or entity.

Stock Options and Stock Appreciation Rights

The plan permits the grant of options covering common stock and the grant of stock appreciation rights. A stock appreciation right is an award that, upon exercise, entitles the participant to receive the excess of the fair market value of a share of common stock on the exercise date over the base price established for the stock appreciation right. Such excess may be paid in common stock, cash, or a combination thereof, as determined by the plan administrator in its discretion. The plan administrator will be able to make grants of stock options and stock appreciation rights under the plan containing such terms as the plan administrator may determine. Stock options and stock appreciation rights may have an exercise price or base price that is no less than the fair market value of our common stock on the date of grant. In general, stock options and stock appreciation rights granted will become exercisable over a period determined by the plan administrator, but in no event will they be exercisable later than ten years from the date of grant.

Restricted Stock, Restricted Stock Units and Phantom Stock Units

Restricted stock is subject to forfeiture prior to the vesting of the award. A restricted stock unit is notional stock that entitles the grantee to receive a share of common stock following the vesting of the restricted stock unit or, in the discretion of the plan administrator, cash equivalent to the value of our common stock. The plan administrator may determine to make grants under the plan of restricted stock and restricted stock units containing such terms as the plan administrator may determine. The plan administrator will determine the period over which restricted stock and restricted stock units granted to plan participants will vest. The plan administrator may base its determination upon the achievement of specified performance goals. Phantom stock units, which represent a notional share of our common stock, may also be granted by the plan administrator under the plan, subject to vesting and forfeiture and other terms and conditions as determined by the plan administrator.

Dividend Equivalent Rights

The plan administrator may grant dividend equivalent rights under the plan, subject to such terms and conditions as determined by the plan administrator in accordance with the terms of the plan.

Unrestricted Stock

The plan administrator may grant shares of our common stock free of restrictions under the plan in respect of past services or other valid consideration.

Other Stock-Based Awards

The plan administrator may, subject to the provisions of the plan, grant other equity-based or equity-related awards in such amounts and subject to such terms and conditions as the plan administrator may determine.

Change in Control

Unless otherwise provided in the instrument evidencing the award, in the event of a change in control of Ocean Rig UDW Inc., as defined in the plan, all outstanding awards will become fully and immediately vested and exercisable.

Term, Termination and Amendment of Plan and Awards

Our board of directors may terminate, suspend or discontinue the plan at any time with respect to any award that has not yet been granted. Unless the plan is terminated earlier, no award may be granted under the plan following the tenth anniversary of the date of the plan's adoption by our board of directors. Our board of directors also has the right to alter or amend the plan or any part of the plan from time to time, subject to shareholder approval in certain circumstances as provided in the plan. The plan administrator may also modify outstanding awards granted under the plan. However, other than adjustments to outstanding awards upon the occurrence of certain unusual or nonrecurring events, generally no change in any outstanding grant may be made that would materially impair the rights or materially increase the obligations of the participant without the consent of the participant.

Awards

Our compensation committee has approved the award under the plan of 153,150 restricted common shares to our management and employees (including 77,150 shares that were subsequently forfeited), of which 28,200 shares have been issued. The remaining 47,800 shares are expected to be issued in 2013 and all 76,000 shares vest ratably over a period of three years. As of December 31, 2012, 2,500 of these shares are vested.

Item 7. Major Shareholders and Related Party Transactions

A. Major Shareholders

The following table sets forth the beneficial ownership of our common shares, as of March 20, 2013, held by:

each person or entity that we know beneficially owns 5% or more of our common stock;

each of our executive officers and directors; and

all our executive officers and directors as a group.

Beneficial ownership is determined in accordance with the SEC's rules. In computing percentage ownership of each person, common shares subject to options held by that person that are currently exercisable or convertible, or exercisable or convertible within 60 days of March 20, 2013, are deemed to be beneficially owned by that person. These shares, however, are not deemed outstanding for the purpose of computing the percentage ownership of any other person. All of our shareholders, including the shareholders listed in the table below, are entitled to one vote for each common share held.

Name and Address of Beneficial Owner(1)	Number of Shares Owned	Percent of Class(2)
Executive Officers and Directors:
George Economou(3)	5,393,289	4.1%
Michael Gregos	-	*
Trygve Arnesen	-	*
Savvas D. Georghiades	-	*
Prokopios (Akis) Tsirigakis	-	*
Anthony Kandylidis(4)	1,684,512	1.3%
Gilles Bocabarteille	-	*
Mark Bessell	-	*
Jan Rune Steinsland	-	*
Executive Officers and Directors as a Group	7,112,466	5.4%
5% Beneficial Owners:
DryShips Inc.(5)	78,301,755	59.4%

*Less than 1.0% of our total outstanding common shares.

(1)	Unless otherwise indicated, the business address of each beneficial owner identified is 10 Skopa Street, Tribune House, 2nd Floor, Office 202, CY 1075, Nicosia, Cyprus.

(2)	Based on 131,725,128 common shares outstanding as of March 20, 2013.

(3)

George Economou, our Chairman, President and Chief Executive Officer, may be deemed to beneficially own 5,061,430 of these shares through Sphinx Investment Corp., a Marshall Islands corporation controlled by Mr. Economou. Mr. Economou may be deemed to beneficially own 79,525 of these shares through Elios Investments Inc., a wholly owned subsidiary of the Entrepreneurial Spirit Foundation, a Lichtenstein foundation, or the Foundation, the beneficiaries of which are Mr. Economou and members of Mr. Economou's family. Mr. Economou may be deemed to beneficially own 145,128 of these shares through Entrepreneurial Spirit Holdings Inc., a Liberian corporation that is wholly owned by the Foundation. Mr. Economou may be deemed to beneficially own 105,357 of these shares through Fabiana Services S.A., a Marshall Islands corporation, of which Mr. Economou is the controlling person. Mr. Economou may be deemed to own 1,849 of these shares through Goodwill Shipping Company Limited, a Malta corporation, of which Mr. Economou is the controlling person.

(4)	Anthony Kandylidis, our Executive Vice President, may be deemed to beneficially own all of these shares through Skidrow Investments Limited, a Marshall Islands corporation controlled by Mr. Kandylidis.

(5)

DryShips is our parent company and a reporting company under the Exchange Act. George Economou, our Chairman, President and Chief Executive Officer, is also the Chairman, President and Chief Executive Officer of DryShips. Information with respect to DryShips and Mr. Economou and their relations to us is discussed under "B.—Related Party Transactions." The business address of DryShips Inc. is 74-76 V. Ipeirou Street, GR 15125 Amaroussion, Greece. In October 2012, DryShips pledged 7,800,000 of these shares as additional collateral under certain of its credit facilities. The terms of the share pledge expire on June 30, 2013. In March 2013, DryShips pledged 1,602,500 of these shares as additional collateral under certain of its credit facilities.

The following transactions account for the significant changes in the percentage of beneficial ownership of our common shares held by our Chairman, President and Chief Executive Officer, Mr. George Economou, and DryShips since the closing of our 2010 Private Offering in December 2010:

Following the 2010 Private Offering, our Chairman, President and Chief Executive Officer, Mr. Economou, was deemed to beneficially own 2,869,428 of our common shares, or 2.38% of our then outstanding common shares, and DryShips owned 103,125,500 of our common shares, or approximately 78.5% of our then outstanding common shares. On October 5, 2011, DryShips completed the partial spin off of us by distributing an aggregate of 2,967,396 of our common shares that DryShips held, including 105 common shares treated of fractional shares, to shareholders of DryShips, including companies affiliated with our Chairman, President and Chief Executive Officer, on a pro rata basis. DryShips also received an aggregate of 255,036 of our common shares, which were returned to DryShips by Deutsche Bank Securities Inc. in connection with the partial spin-off pursuant to a share lending arrangement between DryShips and Deutsche Bank Securities Inc. In November 2011, as partial consideration in connection with the OceanFreight merger, DryShips distributed to OceanFreight shareholders, other than entities controlled by OceanFreight's Chief Executive Officer and our Executive Vice President, Mr. Anthony Kandylidis, an aggregate of 1,541,159 of our common shares that DryShips held. Prior to the completion of the OceanFreight merger, DryShips also distributed an aggregate of 1,570,226 common shares to entities controlled by Mr. Kandylidis as partial consideration for the acquisition of all of their shares of OceanFreight, representing a majority of the then outstanding shares of OceanFreight. On April 17, 2012, DryShips completed the public offering of an aggregate of 11,500,000 of our common shares owned by DryShips. Companies affiliated with our Chairman and Chief Executive Officer purchased a total of 2,185,000 common shares from DryShips in the offering at the public offering price.

As of March 20, 2013, we had 57 shareholders of record, 37 of which were located in the United States and held an aggregate of 57,990,515 of our common shares, representing 44.0% of our outstanding shares of common stock. However, one of the U.S. shareholders of record is CEDE & CO., a nominee of The Depository Trust Company, which held 57,989,290 shares of our common stock as of March 20, 2013. Accordingly, we believe that the shares held by Cede & Co. include shares of common stock beneficially owned by both holders in the United States and non-U.S. beneficial owners.

We are not aware of any arrangements the operation of which may at a subsequent date result in our change of control.

B. Related Party Transactions

All related party transactions are subject to the review and approval of the independent members of our board of directors.

Related Party Agreements

Legal Services

Mr. Savvas D. Georghiades, a member of our board of directors, provides legal services to us and to our predecessor, Primelead Limited, through his law firm, Savvas D. Georghiades, Law Office. For the years ended December 31, 2012, 2011 and 2010, we paid fees of €41,623, €47,390 and €94,235, respectively (or $55,005, $61,365 and $124,880, respectively, based on the Euro/U.S. Dollar exchange rate at December 31, 2012, 2011 and 2010 respectively), for the legal services provided by Mr. Georghiades.

Loans and Guarantees

$562.5 million loan agreements, amended to $495.0 million (the Deutsche Bank credit facilities)

On July 18, 2010, DryShips, our parent company, entered into guarantees in connection with our Deutsche Bank credit facilities. The guarantees by DryShips covered the initial equity contribution and each other equity contribution, the equity collateral, amounts to be paid into the debt service reserve account and each payment of the loan balance. In addition, the guarantees by DryShips contained certain financial covenants measured on the DryShips financial accounts requiring the maintenance of (i) minimum market adjusted equity ratio; (ii) minimum interest coverage ratio; (iii) minimum market value adjusted net worth of DryShips and its subsidiaries; and (iv) minimum amount of free cash and cash equivalents.

On May 14, 2012, we signed amendments to the Deutsche Bank credit facilities to, among other things, remove the payment guarantee of DryShips, subject to reinstatement as discussed below, and remove the financial covenants for DryShips and the cross-default provision relating to DryShips's outstanding indebtedness for its drybulk carrier and tanker fleet. As a result of the amendments, a default by DryShips under one of its loan agreements for its drybulk carrier and tanker fleet will not result in a cross-default under the Deutsche Bank credit facilities that would provide the lenders thereunder with the right to accelerate our outstanding debt. Under the terms of the amended Deutsche Bank credit facilities, in the event of a breach by us of any of the financial covenants contained in our guarantees under the Deutsche Bank credit facilities, the unconditional and irrevocable payment guarantees of DryShips will be reinstated, pursuant to which DryShips will be obligated to pay, upon demand by the lenders, any amount outstanding under the loans upon a failure by us to pay such amount. In addition, DryShips will be required to indemnify the lenders in respect of any losses they incur in respect of any amounts due under the loans that are not recoverable from DryShips under the guarantees and that we fail to pay. The amount payable by DryShips under the guarantees will be limited to $214.0 million with respect to the facility for the Ocean Rig Poseidon and $255.0 million with respect to the facility for the Ocean Rig Mykonos, in each case plus any other amounts that become payable in connection with the payment of such amount. The guarantees will not include any financial covenants applicable to DryShips or cross-default provisions in relation to DryShips's indebtedness for its drybulk carrier and tanker fleet. See "Item 5. Operating and Financial Review and Prospects—B. Liquidity and Capital Resources—Our Debt Agreements—Existing Debt Agreements—Two $562.5 million loan agreements, amended to $495.0 million (the Deutsche Bank credit facilities)."

$800.0 million senior secured term loan agreement

Our $800.0 million senior secured term loan agreement is guaranteed by us and, prior to May 9, 2012, was also guaranteed by DryShips. Under the loan agreement, DryShips was required to maintain (i) minimum liquidity; (ii) a minimum interest coverage ratio; (iii) a minimum market adjusted equity ratio; and (iv) a minimum market value adjusted net worth.

On May 9, 2012, we signed an amendment under our $800.0 million secured term loan agreement to, among other things, terminate the guarantee by DryShips and remove the related covenants and remove the cross-acceleration provisions relating to DryShips's indebtedness for its drybulk carrier and tanker fleet and our indebtedness under our other credit facilities. As a result of the amendment, a default by DryShips under one of its loan agreements for its drybulk carrier and tanker fleet or a default by us under one of our other credit facilities and the acceleration of the related debt will not result in a cross-default under our $800.0 million secured term loan agreement that would provide its lenders with the right to accelerate the outstanding debt under the loan agreement. See "Item 5. Operating and Financial Review and Prospects—B. Liquidity and Capital Resources—Our Debt Agreements—Existing Debt Agreements —$800.0 million senior secured term loan agreement."

Global Services Agreement

On December 1, 2010, DryShips, our parent company, entered into a Global Services Agreement with Cardiff Marine, a company controlled by our Chairman, President and Chief Executive Officer, Mr. George Economou, effective December 21, 2010, pursuant to which DryShips engaged Cardiff to act as consultant on matters of chartering and sale and purchase transactions for the offshore drilling units operated by us. Under the Global Services Agreement, Cardiff, or its subcontractor, (i) provided consulting services related to the identification, sourcing, negotiation and arrangement of new employment for offshore assets of DryShips and its subsidiaries, including our drilling units; and (ii) identified, sourced, negotiated and arranged the sale or purchase of the offshore assets of DryShips and its subsidiaries, including our drilling units. In consideration of such services, DryShips paid Cardiff a fee of 1.0% in connection with employment arrangements and 0.75% in connection with sale and purchase activities. We did not pay for services provided in accordance with this agreement. The costs of services we received under the Global Services Agreement were expensed in our consolidated statement of operations or capitalized as directly attributable to construction costs under "Rig under construction". The payment by DryShips for services provided to us under the agreement was deemed an equity contribution to us and is recorded as shareholders' contribution to shareholders' equity.

Except as provided below, the Global Services Agreement applied to all offshore drilling contracts we entered into after December 21, 2010, as well as the drilling contract with Cairn Energy plc, or Cairn, for the Ocean Rig Corcovado, which commenced in January 2011 and was completed in November 2011, and the drilling contracts with Vanco Cote d'Ivoire Ltd. and Vanco Ghana Ltd for the Ocean Rig Olympia, which commenced in March 2011, were novated to Tullow Ghana in December 2011 and were completed in the second quarter of 2012. The Global Services Agreement did not apply to the agreement with Petrobras Oil & Gas regarding the early termination of the drilling contract with Petrobras Oil & Gas for the Leiv Eiriksson and the replacement of the Leiv Eiriksson under the drilling contract with Petrobras Oil & Gas with the Ocean Rig Poseidon, which occurred in April 2011, the drilling contract with Cairn for the Leiv Eiriksson, which commenced in April 2011 and was completed in November 2011 and the drilling contract with Borders & Southern plc for the Leiv Eiriksson, which commenced in November 2011 and was completed in the fourth quarter of 2012.

During the years ended December 31, 2012 and 2011, we recorded expenses of a total of approximately $6.2 and $2.4 million relating to employment arrangements, respectively, and $1.0 and $4.9 million relating to sale and purchase activities, respectively. We did not record any expenses in connection with the Global Services Agreement during the year ended December 31, 2010.

Effective January 1, 2013, the Global Services Agreement was terminated by mutual agreement of the parties. Also effective January 1, 2013, Ocean Rig Management Inc., or Ocean Rig Management, our wholly-owned subsidiary, entered into a new services agreement, or the Ocean Rig Services Agreement, with Cardiff Drilling, a company controlled by our Chairman, President and Chief Executive Officer, on the same terms and conditions as the Global Services Agreement, except that under the Ocean Rig Services Agreement, Ocean Rig Management is obligated to pay directly the fees of 1.0% in consideration of employment arrangements under the agreement and $0.75% in consideration of purchase and sale activities under the agreement, whereas under the Global Services Agreement, those fees were paid by DryShips.

Consultancy Agreement

As of September 1, 2010, DryShips, our parent company, entered into an agreement, or the DryShips Consultancy Agreement, with Vivid Finance, a company controlled by our Chairman, President and Chief Executive Officer, Mr. George Economou, whereby DryShips engaged Vivid Finance to act as a consultant on financing matters for DryShips and its affiliates, subsidiaries or holding companies, including us, as directed by DryShips. Under the DryShips Consultancy Agreement, Vivid Finance provided us with consulting services relating to (i) the identification, sourcing, negotiation and arrangement of new loan and credit facilities, interest swap agreements, foreign currency contracts and forward exchange contracts; (ii) the raising of equity or debt in the public capital markets; and (iii) the renegotiation of existing loan facilities and other debt instruments. In consideration for these services, Vivid Finance was entitled to a fee of twenty basis points, or 0.20%, on the total transaction amount. We did not pay or reimburse DryShips or its affiliates for services provided to us in accordance with the DryShips Consultancy Agreement. However, we recorded expenses incurred under the DryShips Consultancy Agreement in our income statement and as a shareholder's contribution (additional paid-in capital) to capital when they were incurred. During the years ended December 31, 2012, 2011 and 2010, we recorded expenses of a total of approximately $10.8 million $5.2 million and $1.0 million, respectively, in fees from Vivid Finance with respect our financing arrangements.

Effective January 1, 2013, Ocean Rig Management, our wholly-owned subsidiary, entered into a separate consultancy agreement, or the Ocean Rig Consultancy Agreement, with Vivid Finance, on the same terms and conditions as the DryShips Consultancy Agreement, except that under the Ocean Rig Consultancy Agreement, Ocean Rig Management is obligated to pay directly the fee of 0.20% to Vivid Finance on the total transaction amount in consideration of the services provided, whereas under the DryShips Consultancy Agreement, this fee was paid by DryShips. In connection with Ocean Rig Management's entry into the Ocean Rig Consultancy Agreement, the DryShips Consultancy Agreement was amended, effective as of January 1, 2013, to limit the scope of the services provided under the agreement to DryShips and its subsidiaries or affiliates, except for Ocean Rig UDW Inc. and its subsidiaries. In essence, post-amendment, the DryShips Consultancy Agreement is in effect for DryShips's tanker and drybulk shipping segments only.

Employment Agreements

See "Item 6. Directors, Senior Management and Employees—D. Employees—Employment Agreements."

Registration Rights Agreement

On March 20, 2012, we entered into a registration rights agreement with DryShips, pursuant to which DryShips has the right, subject to certain restrictions, to require us to register under the Securities Act a total of 97,301,755 of our common shares that it owned as of the date of the agreement. On April 17, 2012, DryShips completed the sale of 11,500,000 of our common shares that were covered by the registration rights agreement.

C. Interests of experts and counsel

Not applicable.

Item 8. Financial Information

A. Consolidated statements and other financial information

See "Item 18. Financial Statements."

Legal Proceedings

Class Action Lawsuit

On October 13, 2011, a putative shareholder class action lawsuit entitled Litwin v. OceanFreight, Inc. et al. was filed in the United States District Court for the Southern District of New York against OceanFreight, DryShips, the Company, Pelican Stockholdings Inc. and certain current and former directors of OceanFreight, or collectively, the Defendants (Case No. 1:11-cv-7218). The complaint was then amended on October 14, 2011. The plaintiff alleged violations of certain provisions of the Exchange Act and the regulations thereunder, as well as breaches of fiduciary duties owed to OceanFreight by its directors, purportedly aided and abetted by the other Defendants, in connection with OceanFreight's agreement to merge with Pelican Stockholdings Inc., a wholly-owned subsidiary of the Company.

The amended complaint sought to rescind the agreement to merge and enjoin the merger discussed above, as well as an award of actual and punitive damages. The plaintiff made a motion for a temporary restraining order and preliminary injunction to delay the OceanFreight merger, which motion was denied on November 2, 2011. The plaintiff did not appeal the denial of her motion. On January 10, 2012, she voluntarily dismissed all her claims alleged in the amended complaint, with prejudice, as to all Defendants, including the Company. The case is now closed.

Import/export Duties in Angola

The Leiv Eiriksson operated in Angola during the period from 2002 to 2007. Our manager in Angola during this period has made a legal claim in the London High Court (Commercial Court) for reimbursement of import/export duties for two export/importation events from 2002 to 2007 retroactively levied by the Angolan government. Agreement was reached between the parties to this claim for an amount of $6.1 million, which was paid by our relevant subsidiary to the claimant on May 24, 2012, in full and final settlement of the London court proceedings.

Other Legal Proceedings

With the exception of the matters discussed above, we are not involved in any legal proceedings or disputes that we believe will have a significant effect on our business, financial position, and results of operations or liquidity. From time to time, we may be subject to legal proceedings and claims in the ordinary course of business. It is expected that these claims would be covered by insurance if they involved liabilities such as those that arise from a collision, other marine casualty, damage to cargoes, oil pollution, death or personal injuries to crew, subject to customary deductibles. Those claims, even if lacking merit, could result in the expenditure of significant financial and managerial resources.

Dividend Policy

Our long-term objective is to pay a regular dividend in support of our main objective to maximize shareholder returns. However, we have not paid any dividends in the past and we are currently focused on the development of capital intensive projects in line with our growth strategy and this focus will limit any dividend payment in the medium term. Because we are a holding company with no material assets other than the shares of our subsidiaries through which we conduct our operations, our ability to pay dividends will depend on our subsidiaries distributing their earnings and cash flow to us. In addition, under certain of our debt agreements, our ability to pay dividends to our shareholders is restricted.

Any future dividends declared will be at the discretion of our board of directors and will depend upon our financial condition, earnings and other factors, including the covenants contained in our debt agreements. See "Item 5. Operating and Financial Review and Prospects—B. Liquidity and Capital Resources—Our Debt Agreements—Existing Debt Agreements." Our ability to pay dividends is also subject to Marshall Islands law, which generally prohibits the payment of dividends other than from operating surplus or while a company is insolvent or would be rendered insolvent upon the payment of such dividend.

We believe that, under current U.S. law, any future dividend payments from our then current and accumulated earnings and profits, as determined under U.S. federal income tax principles, would constitute "qualified dividend income" and, as a consequence, non-corporate U.S. shareholders would generally be subject to the same preferential U.S. federal income tax rates applicable to long-term capital gains with respect to such dividend payments. Distributions in excess of our earnings and profits, as so calculated, will be treated first as a non-taxable return of capital to the extent of a U.S. stockholder's tax basis in its shares of common stock on a dollar-for-dollar basis and thereafter as capital gain. Please see "Item 10. Additional Information—E. Taxation" for additional information relating to the tax treatment of our dividend payments.

B. Significant Changes

See note 18 of "Item 18. Financial Statements"

Item 9. The Offer and Listing

Since October 6, 2011, the primary trading market for our common shares has been the NASDAQ Global Select Market, on which our shares are listed under the symbol "ORIG." On September 19, 2011 our common shares began "when issued" trading and on October 6, 2011 commenced "regular way" trading on the NASDAQ Global Select Market. The secondary trading market for our common stock is the Norwegian OTC Market, on which our common shares have been trading since the pricing the private offering on December 15, 2010.

The table below sets forth the high and low closing prices of our common shares for each of the periods indicated, as reported by the NASDAQ Global Select Market and the Norwegian OTC Market. The quoted prices from the Norwegian OTC Market reflect intermittent transactions that were privately negotiated. Accordingly, the quoted prices are not necessarily indicative of the share prices that would have been obtained had there been a more active market for our common shares. The trading prices for our common shares on the Norwegian OTC Market are quoted in Norwegian kroner.

For the Year Ended	Low (NASDAQ)		High (NASDAQ)			Low(1) (OTC)		High(1) (OTC)
December 31, 2010		-			-		99.00(2)		103.00(2)
December 31, 2011	$	11.96(3)	$	16.00(3)			72.00		125.00
December 31, 2012	$	11.75	$	18.17			73.00		102.00
For the Quarter Ended
March 31, 2011		-		-			104.00		125.00
June 30, 2011		-		-			99.00		118.00
September 30, 2011		-		-			79.50		97.00
December 31, 2011	$	$11.96(3)	$	16.00(3)			72.00		90.00
March 31, 2012	$	11.75	$	17.86			73.00		97.00
June 30, 2012	$	13.04	$	18.17			78.00		102.00
September 30, 2012	$	13.59	$	18.16			88.00		101.00
December 31, 2012	$	14.69	$	16.51			82.00		94.00

For the Month Ended
September 2012	$	16.31	$	18.16	92.50		101.00
October 2012	$	15.18	$	16.50	94.00		94.00
November 2012	$	14.69	$	16.51	-	(5)	-	(5)
December 2012	$	14.72	$	15.75	82.00		82.00
January 2013	$	15.00	$	17.47	-	(5)	-	(5)
February 2013	$	17.57	$	17.71	-	(5)	-	(5)
March 2013	$	13.76	$	15.73	-	(5)	-	(5)

____________________

(1)

As reported in Norwegian Kroner. As of March 21, 2013, the U.S. Dollar/Norwegian Kroner exchange rate was $1.00/NOK5.840.

(2)

For the period from December 15, 2010, the date on which our common shares began trading on Norwegian OTC Market, until the end of the period.

(3)

For the period from October 6, 2011, the date on which our common shares began "regular way" trading on the NASDAQ Global Select Market, until the end of the period.

(4)

Through March 20, 2013.

(5)

There were no trades during this period.

On November 2, 2011, the Board of Directors of Oslo Bшrs resolved to admit our common shares to listing on Oslo Bшrs or, alternatively, Oslo Axess, subject to our compliance with certain customary listing requirements of the Oslo Bшrs. The Chief Executive Officer of Oslo Bшrs is authorized to decide whether the Company should be listed on Oslo Bшrs or Oslo Axess and to fix the date of listing. We have requested an indefinite extension for the proposed listing date on the Oslo Bors or, alternatively, the Oslo Axess, which was originally scheduled to be no later than December 16, 2011.

We cannot guarantee that our common shares will be listed on the Oslo Bors or, alternatively, the Oslo Axess. In addition, at our 2011 Annual General Meeting of Shareholders held on December 23, 2011, our shareholders approved the delisting of our common shares from the Oslo Bors, or, alternatively, the Oslo Axess, as applicable, if and only if such delisting should be determined by our board of directors to be in our best interests and those of our shareholders, and authorized our board of directors, in its discretion, to apply for and effect such delisting at any time on our prior to our 2016 Annual General Meeting of Shareholders.

Item 10. Additional Information

A. Share capital

Not applicable.

B. Memorandum and Articles of Association

Our current second amended and restated articles of incorporation and second amended and restated bylaws have been filed as Exhibits 3.1 and 3.2, respectively, to our Registration Statement on Form F-4 (File No. 333-175940) filed with the SEC on August 1, 2011. The information contained in these exhibits is hereby incorporated by reference in this annual report.

Information required by "Item 10. Additional Information—B. Memorandum and Articles of Association" of Form 20-F is hereby incorporated by reference to the section entitled "Description of Capital Stock" in our Registration Statement on Form F-3ASR (Registration Statement No. 333-184450), filed with the SEC on October 16, 2012, provided that as of the date of this annual report, we had 131,725,128 common shares issued and outstanding.

C. Material Contracts

We refer you to "Item 5. Operating and Financial Review and Prospects —B. Liquidity and Capital Resources—Credit Facilities," "Item 7. Major Shareholders and Related Party Transactions—B. Related Party Transactions" for a discussion of our material agreements that we have entered into outside the ordinary course of our business during the two-year period immediately preceding the date of this annual report.

Other than the agreements discussed in the aforementioned sections of this annual report, we have no material contracts, other than contracts entered into in the ordinary course of business, to which we or any member of the group is a party.

D. Exchange controls

Under Marshall Islands law, there are currently no restrictions on the export or import of capital, including foreign exchange controls or restrictions that affect the remittance of dividends, interest or other payments to non-resident holders of our common shares.

E. Taxation

The following is a discussion of the material Marshall Islands and U.S. federal income tax considerations relevant to an investment decision by a U.S. Holder and a Non-U.S. Holder, each as defined below with respect to the common shares. This discussion does not purport to deal with the tax consequences of owning common shares to all categories of investors, some of which, such as dealers in securities, U.S. Holders whose functional currency is not the United States dollar and investors that own, actually or under applicable constructive ownership rules, 10% or more of our common shares, may be subject to special rules. This discussion deals only with holders who acquire common shares in this offering and hold the common shares as a capital asset. You are encouraged to consult your own tax advisors concerning the overall tax consequences arising in your own particular situation under U.S. federal, state, local or foreign law of the ownership of common shares.

Marshall Islands Tax Considerations

The following are the material Marshall Islands tax consequences of our activities to the Company and our shareholders. We are incorporated in the Marshall Islands. Under current Marshall Islands law, we are not subject to tax on income or capital gains, and no Marshall Islands withholding tax will be imposed upon payments of dividends by us to our shareholders.

U.S. Federal Income Tax Considerations

The following are the material U.S. federal income tax consequences relevant to an investment decision by a U.S. Holder and a Non-U.S. Holder, each as defined below, with respect to our common shares. The following discussion of U.S. federal income tax matters is based on the U.S. Internal Revenue Code of 1986, or the Code, judicial decisions, administrative pronouncements, and existing and proposed regulations issued by the U.S. Department of the Treasury, all of which are subject to change, possibly with retroactive effect.

This discussion does not purport to deal with the tax consequences of owning our common shares to all categories of investors, some of which, such as dealers in securities, investors whose functional currency is not the U.S. Dollar and investors that own, actually or under applicable constructive ownership rules, 10% or more of our shares, may be subject to special rules. This discussion deals only with holders who purchase common shares in connection with this offering and hold the common shares as a capital asset. You are encouraged to consult your own tax advisors concerning the overall tax consequences arising in your own particular situation under U.S. federal, state, local or foreign law of the ownership of our common shares. Unless otherwise noted, references in the following discussion to the "Company," "we" and "us" are to Ocean Rig UDW Inc. and its subsidiaries on a consolidated basis.

If a partnership holds common shares, the tax treatment of a partner will generally depend upon the status of the partner and upon the activities of the partnership. If you are a partner in a partnership holding common shares, you are encouraged to consult your tax advisor.

Taxation of U.S. Holders

As used herein, the term "U.S. Holder" means a beneficial owner of common shares that is a U.S. citizen or resident, U.S. corporation or other U.S. entity taxable as a corporation, an estate the income of which is subject to U.S. federal income taxation regardless of its source, or a trust if a court within the United States is able to exercise primary jurisdiction over the administration of the trust and one or more U.S. persons have the authority to control all substantial decisions of the trust.

Distributions

Subject to the discussion of passive foreign investment companies below, any distributions made by us with respect to our common shares to a U.S. Holder, will generally constitute dividends, to the extent of our current or accumulated earnings and profits, as determined under U.S. federal income tax principles. Distributions in excess of our earnings and profits will be treated first as a nontaxable return of capital to the extent of the U.S. Holder's tax basis in his common shares on a dollar-for-dollar basis and thereafter as capital gain. Because we are not a U.S. corporation, U.S. Holders that are corporations will not be entitled to claim a dividends received deduction with respect to any distributions they receive from us. Dividends paid with respect to our common shares will generally be treated as "passive category income" or, in the case of certain types of U.S. Holders, "general category income" for purposes of computing allowable foreign tax credits for U.S. foreign tax credit purposes.

Dividends paid on our common shares to a U.S. Holder who is an individual, trust or estate (a "U.S. Individual Holder") will generally be treated as "qualified dividend income" that is taxable to such U.S. Individual Holders at preferential tax rates provided that (1) the common share is readily tradable on an established securities market in the United States (such as the NASDAQ Global Select Market, on which our common shares will be listed); (2) we are not a passive foreign investment company for the taxable year during which the dividend is paid or the immediately preceding taxable year (which we do not believe we are, have been or will be); and (3) the U.S. Individual Holder has owned the common shares for more than 60 days in the 121-day period beginning 60 days before the date on which the common shares become ex-dividend. There is no assurance that any dividends paid on our common shares will be eligible for these preferential rates in the hands of a U.S. Individual Holder. Any dividends paid by us which are not eligible for these preferential rates will be taxed as ordinary income to a U.S. Holder.

Special rules may apply to any "extraordinary dividend" generally, a dividend in an amount which is equal to or in excess of ten percent of a stockholder's adjusted basis (or fair market value in certain circumstances) in a common share paid by us. If we pay an "extraordinary dividend" on our common shares that is treated as "qualified dividend income," then any loss derived by a U.S. Individual Holder from the sale or exchange of such common shares will be treated as long-term capital loss to the extent of such dividend.

Sale, Exchange or other Disposition of Common Shares

Assuming we do not constitute a passive foreign investment company for any taxable year, a U.S. Holder generally will recognize taxable gain or loss upon a sale, exchange or other disposition of our common shares in an amount equal to the difference between the amount realized by the U.S. Holder from such sale, exchange or other disposition and the U.S. Holder's tax basis in such stock. Such gain or loss will be treated as long-term capital gain or loss if the U.S. Holder's holding period is greater than one year at the time of the sale, exchange or other disposition. Such capital gain or loss will generally be treated as U.S. source income or loss, as applicable, for U.S. foreign tax credit purposes. A U.S. Holder's ability to deduct capital losses is subject to certain limitations.

Passive Foreign Investment Company Status and Significant Tax Consequences

Special U.S. federal income tax rules apply to a U.S. Holder that holds stock in a foreign corporation classified as a passive foreign investment company (a "PFIC") for U.S. federal income tax purposes. In general, a foreign corporation will be treated as a PFIC with respect to a U.S. shareholder in such foreign corporation, if, for any taxable year in which such shareholder holds stock in such foreign corporation, either:

at least 75% of the corporation's gross income for such taxable year consists of passive income (e.g., dividends, interest, capital gains and rents derived other than in the active conduct of a rental business); or

at least 50% of the average value of the assets held by the corporation during such taxable year produce, or are held for the production of, passive income.

For purposes of determining whether a foreign corporation is a PFIC, it will be treated as earning and owning its proportionate share of the income and assets, respectively, of any of its subsidiary corporations in which it owns at least 25% of the value of the subsidiary's stock. If Ocean Rig UDW Inc. is treated as a PFIC, then a U.S. person would be treated as indirectly owning shares of its foreign corporate subsidiaries for purposes of the PFIC rules.

Income earned by a foreign corporation in connection with the performance of services would not constitute passive income. By contrast, rental income would generally constitute "passive income" unless the foreign corporation is treated under specific rules as deriving its rental income in the active conduct of a trade or business.

We do not believe that we are currently a PFIC, although we may have been a PFIC for certain prior taxable years. Based on our current operations and future projections, we do not believe that we have been, are, or will be a PFIC with respect to any taxable year beginning with the 2009 taxable year. Although we intend to conduct our affairs in the future in a manner to avoid being classified as a PFIC, we cannot assure you that the nature of our operations will not change in the future.

Special U.S. federal income tax elections have been made or will be made in respect of certain of our subsidiaries. The effect of these special U.S. tax elections is to ignore or disregard the subsidiaries for which elections have been made as separate taxable entities and to treat them as part of their sole shareholder. Therefore, for purposes of the following discussion, for each subsidiary for which such an election has been made, the shareholder of such subsidiary, and not the subsidiary itself, will be treated as the owner of the subsidiary's assets and as receiving the subsidiary's income.

As discussed more fully below, if we were to be treated as a PFIC for any taxable year, a U.S. Holder would be subject to different taxation rules depending on whether the U.S. Holder makes an election to treat us as a "Qualified Electing Fund," which election we refer to as a "QEF election" or makes a "mark-to market" election with respect to our stock. In addition, if we were to be treated as a PFIC for any taxable year after 2010, a U.S. Holder would be required to file an annual report with the Internal Revenue Service for that year with respect to such holder's common shares.

Taxation of U.S. Holders Making a Timely QEF Election

If a U.S. Holder makes a timely QEF election, which U.S. Holder we refer to as an "Electing Holder," the Electing Holder must report each year for U.S. federal income tax purposes his pro rata share of our ordinary earnings and our net capital gain, if any, for our taxable year that ends with or within the taxable year of the Electing Holder, regardless of whether or not distributions were received from us by the Electing Holder. The Electing Holder's adjusted tax basis in the common shares will be increased to reflect taxed but undistributed earnings and profits. Distributions of earnings and profits that had been previously taxed will result in a corresponding reduction in the adjusted tax basis in the common shares and will not be taxed again once distributed. An Electing Holder would generally recognize capital gain or loss on the sale, exchange or other disposition of the common shares. A U.S. Holder would make a QEF election with respect to any year that our company is a PFIC by filing Internal Revenue Service Form 8621 with his U.S. federal income tax return. If we were aware that we were to be treated as a PFIC for any taxable year, we would, if possible, provide each U.S. Holder with all necessary information in order to make the QEF election described above. It should be noted that we may not be able to provide such information if we did not become aware of our status as a PFIC in a timely manner.

Taxation of U.S. Holders Making a "Mark-to-Market" Election

Alternatively, if we were to be treated as a PFIC for any taxable year and our stock is treated as "marketable stock," a U.S. Holder would be allowed to make a "mark-to-market" election with respect to our common shares, provided the U.S. Holder completes and files IRS Form 8621 in accordance with the relevant instructions and related Treasury Regulations. Since our stock is traded on the NASDAQ Global Select Market, we believe that our stock is "marketable stock" for this purpose. If the "mark-to-market" election is made, the U.S. Holder generally would include as ordinary income in each taxable year the excess, if any, of the fair market value of the common shares at the end of the taxable year over such holder's adjusted tax basis in the common shares. The U.S. Holder would also be permitted an ordinary loss in respect of the excess, if any, of the U.S. Holder's adjusted tax basis in the common shares over its fair market value at the end of the taxable year, but only to the extent of the net amount previously included in income as a result of the mark-to-market election. A U.S. Holder's tax basis in his common shares would be adjusted to reflect any such income or loss amount. Gain realized on the sale, exchange or other disposition of the common shares would be treated as ordinary income, and any loss realized on the sale, exchange or other disposition of the common shares would be treated as ordinary loss to the extent that such loss does not exceed the net mark-to-market gains previously included by the U.S. Holder.

Taxation of U.S. Holders Not Making a Timely QEF Election or Mark-to-Market Election

Finally, if we were to be treated as a PFIC for any taxable year, a U.S. Holder who does not make a QEF election (or a mark-to-market election, if such election is available) for that year, whom we refer to as a "Non-Electing Holder," would be subject to special rules with respect to (1) any excess distribution (i.e., the portion of any distributions received by the Non-Electing Holder on the common shares in a taxable year in excess of 125 % of the average annual distributions received by the Non-Electing Holder in the three preceding taxable years, or, if shorter, the Non-Electing Holder's holding period for the common shares), and (2) any gain realized on the sale, exchange or other disposition of the common shares. Under these special rules:

the excess distribution or gain would be allocated ratably over the Non-Electing Holders' aggregate holding period for the common shares;

the amount allocated to the current taxable year and any taxable year before we became a PFIC would be taxed as ordinary income; and

the amount allocated to each of the other taxable years would be subject to tax at the highest rate of tax in effect for the applicable class of taxpayer for that year, and an interest charge for the deemed deferral benefit would be imposed with respect to the resulting tax attributable to each such other taxable year.

These penalties would not apply to a pension or profit sharing trust or other tax-exempt organization that did not borrow funds or otherwise utilize leverage in connection with its acquisition of the common shares. If a Non-Electing Holder who is an individual dies while owning the common shares, such holder's successor generally would not receive a step-up in tax basis with respect to such stock.

Taxation of "Non-U.S. Holders"

A beneficial owner of common shares that is not a U.S. Holder (other than a partnership) is referred to herein as a "Non-U.S. Holder."

Dividends on Common Shares

Non-U.S. Holders generally will not be subject to U.S. federal income tax or withholding tax on dividends received from us with respect to our common shares, unless that income is effectively connected with the Non-U.S. Holder's conduct of a trade or business in the United States. If the Non-U.S. Holder is entitled to the benefits of a U.S. income tax treaty with respect to those dividends, that income is taxable only if it is attributable to a permanent establishment maintained by the Non-U.S. Holder in the United States.

Sale, Exchange or Other Disposition of Common Shares

Non-U.S. Holders generally will not be subject to U.S. federal income tax or withholding tax on any gain realized upon the sale, exchange or other disposition of our common shares, unless:

the gain is effectively connected with the Non-U.S. Holder's conduct of a trade or business in the United States. If the Non-U.S. Holder is entitled to the benefits of an income tax treaty with respect to that gain, that gain is taxable only if it is attributable to a permanent establishment maintained by the Non-U.S. Holder in the United States; or

the Non-U.S. Holder is an individual who is present in the United States for 183 days or more during the taxable year of disposition and other conditions are met.

If the Non-U.S. Holder is engaged in a U.S. trade or business for U.S. federal income tax purposes, the income from the common shares, including dividends and the gain from the sale, exchange or other disposition of the shares that is effectively connected with the conduct of that trade or business will generally be subject to regular U.S. federal income tax in the same manner as discussed in the previous section relating to the taxation of U.S. Holders. In addition, if you are a corporate Non-U.S. Holder, your earnings and profits that are attributable to the effectively connected income, which are subject to certain adjustments, may be subject to an additional branch profits tax at a rate of 30%, or at a lower rate as may be specified by an applicable income tax treaty.

Backup Withholding and Information Reporting

In general, dividend payments, or other taxable distributions, made within the United States to a holder will be subject to information reporting requirements. Such payments will also be subject to "backup withholding" if paid to a non-corporate U.S. Holder who:

fails to provide an accurate taxpayer identification number;

is notified by the Internal Revenue Service that he has failed to report all interest or dividends required to be shown on his federal income tax returns; or

in certain circumstances, fails to comply with applicable certification requirements.

If a holder sells his common shares to or through a U.S. office or broker, the payment of the proceeds is subject to both U.S. backup withholding and information reporting unless the holder establishes an exemption. If a holder sells his common shares through a non-U.S. office of a non-U.S. broker and the sales proceeds are paid to the holder outside the United States then information reporting and backup withholding generally will not apply to that payment. However, U.S. information reporting requirements, but not backup withholding, will apply to a payment of sales proceeds, including a payment made to a holder outside the United States, if the holder sells his common shares through a non-U.S. office of a broker that is a U.S. person or has some other contacts with the United States.

Backup withholding is not an additional tax. Rather, a taxpayer generally may obtain a refund of any amounts withheld under backup withholding rules that exceed the taxpayer's income tax liability by filing a refund claim with the IRS.

Pursuant to recently enacted legislation, individuals who are U.S. Holders (and to the extent specified in applicable Treasury regulations, certain individuals who are Non-U.S. Holders and certain U.S. entities) who hold "specified foreign financial assets" (as defined in Section 6038D of the Code) are required to file IRS Form 8938 with information relating to the asset for each taxable year in which the aggregate value of all such assets exceeds $75,000 at any time during the taxable year or $50,000 on the last day of the taxable year (or such higher dollar amount as prescribed by applicable Treasury regulations). Specified foreign financial assets would include, among other assets, the common shares, unless the shares held through an account maintained with a U.S. financial institution. Substantial penalties apply to any failure to timely file IRS Form 8938, unless the failure is shown to be due to reasonable cause and not due to willful neglect. Additionally, in the event an individual U.S. Holder (and to the extent specified in applicable Treasury regulations, an individual Non-U.S. Holder or a U.S. entity) that is required to file IRS Form 8938 does not file such form, the statute of limitations on the assessment and collection of U.S. federal income taxes of such holder for the related tax year may not close until three years after the date that the required information is filed. U.S. Holders (including U.S. entities) and Non-U.S. Holders are encouraged consult their own tax advisors regarding their reporting obligations under this legislation.

Other Tax Considerations

In addition to the tax consequences discussed above, we may be subject to tax in one or more other jurisdictions where we conduct activities. The amount of any such tax imposed upon our operations may be material.

We provide offshore drilling services to third parties through our fully owned subsidiaries. Such services may be provided in countries where the tax legislation subjects drilling revenue to withholding tax or other corporate taxes, and where the operating cost may also be increased due to tax requirements. The amount of such taxable income and liability will vary depending upon the level of our operations in such jurisdiction in any given taxable year. Distributions from our subsidiaries may be subject to withholding tax.

We do not benefit from income tax positions that we believe are more likely than not to be disallowed upon challenge by a tax authority. If any tax authority successfully challenges our operational structure, inter-company pricing policies or the taxable presence of our key subsidiaries in certain countries; or if the terms of certain income tax treaties are interpreted in a manner that is adverse to our structure; or if we lose a material tax dispute in any country, particularly in the United States, Canada, the U.K., Brazil, Turkey, Angola, Cyprus, Korea, Ghana, Netherlands, Ivory Coast, Tanzania, Falkland Islands, Greenland, Equatorial Guinea or Norway, our effective tax rate on our world-wide earnings could increase substantially and our earnings and cash flows from operations could be materially adversely affected.

F. Dividends and Paying Agents

Not applicable.

G. Statement by Experts

Not applicable.

H. Documents on Display

We file reports and other information with the SEC. These materials, including this annual report and the accompanying exhibits, may be inspected and copied at the public reference facilities maintained by the SEC at 100 F Street, N.E., Washington, D.C. 20549, or from the SEC's website http://www.sec.gov. You may obtain information on the operation of the public reference room by calling 1 (800) SEC-0330 and you may obtain copies at prescribed rates. Our filings are also available on our website at http://www.ocean-rig.com. This web address is provided as an inactive textual reference only. Information on our website does not constitute a part of this annual report.

I. Subsidiary Information

Not applicable.

Item 11. Quantitative and Qualitative Disclosures about Market Risk

Overview

We are exposed to a number of different financial market risks arising from our normal business activities. Financial market risk is the possibility that fluctuations in currency exchange rates and interest rates will affect the value of our assets, liabilities or future cash flows.

To reduce and manage these risks, management periodically reviews and assesses its primary financial market risks. Once risks are identified, appropriate action is taken to mitigate the specific risks. The primary strategy used to reduce our financial market risks is the use of derivative financial instruments where appropriate. Derivatives are used periodically in order to hedge our ongoing operational exposures as well as transaction-specific exposures. When the use of derivatives is deemed appropriate, only conventional derivative instruments are used. These may include interest rate swaps, forward contracts and options.

It is our policy to enter into derivative financial instruments only with highly rated financial institutions. We use derivatives only for the purposes of managing risks associated with interest rate and currency exposure.

Interest Rate Risk

Our exposure to market risk for changes in interest rates relates primarily to our long-term and short-term debt. The international drilling industry is capital intensive, requiring significant amounts of investment. Much of this investment is provided in the form of long-term debt. Our debt usually contains interest rates that fluctuate with LIBOR. Increasing interest rates could adversely impact future earnings.

Historically, we have been subject to market risks relating to changes in interest rates, because we have had significant amounts of floating rate debt outstanding. We manage this risk by entering into interest rate swap agreements in which we exchange fixed and variable interest rates based on agreed upon notional amounts. We use such derivative financial instruments as risk management tools and not for speculative or trading purposes. In addition, the counterparty to the derivative financial instrument is a major financial institution in order to manage exposure to nonperformance counterparties.

As of December 31, 2012, we had a total of 12 interest rate swap, cap and floor agreements, maturing from September 2013 through November 2017. As of December 31, 2011 we had a total of seven interest rate swap, cap and floor agreements, maturing from September 2013 through November 2017. These agreements are entered into in order to hedge our exposure to interest rate fluctuations with respect to our borrowings. See "Item 5. Operating and Financial Review and Prospects—B. Liquidity and Capital Resources—Swap Agreements."

Our interest expense is affected by changes in the general level of interest rates. As an indication of the extent of our sensitivity to interest rate changes, an increase in LIBOR of 1%, with all other variables held constant, would have increased our net loss and decreased our cash flows for the year ended December 31, 2012 by approximately $29.1 million, based on our total outstanding debt level at December 31, 2012. A 1% increase in LIBOR, with all other variables held constant, would have increased our interest expense for the year ended December 31, 2012 from $135.8 million to $164.9 million.

Foreign Currency Exchange Risk

We generate a substantial portion of our revenues in U.S. dollars; however, a portion of our revenue under our drilling contracts with Petrobras Brazil for the Ocean Rig Corcovado and the Ocean Rig Mykonos is, and a portion of our revenue under our drilling contract with Repsol for our seventh generation drillship scheduled to be delivered in July 2013 will be, receivable in Brazilian Real. In addition, for the year ended December 31, 2012, we incurred approximately 61% of our operating expenses and the majority of our management expenses in currencies other than the U.S. dollar. For accounting purposes, expenses incurred in currencies other than the U.S. dollar are converted into U.S. dollars at the exchange rate prevailing on the date of each transaction. Because a significant portion of our expenses are incurred in currencies other than the U.S. dollar, our expenses may from time to time increase relative to our revenues as a result of fluctuations in exchange rates, which could affect the amount of net income that we report in future periods. As of December 31, 2012, the net effect of a 10% adverse movement in U.S. dollar/ currencies other than the U.S. dollar exchange rates would have resulted in an increase of $ 39.2 million in our loss before taxes for the year ended December 31, 2012.

Our international operations expose us to foreign exchange risk. We use a variety of techniques to minimize exposure to foreign exchange risk, such as the use of foreign exchange derivative instruments. Fluctuations in foreign currencies typically have not had a material impact on our overall results. In situations where payments of local currency do not equal local currency requirements, foreign exchange derivative instruments, specifically foreign exchange forward contracts, or spot purchases, may be used to mitigate foreign currency risk. A foreign exchange forward contract obligates us to exchange predetermined amounts of specified foreign currencies at specified exchange rates on specified dates or to make an equivalent U.S. dollar payment equal to the value of such exchange. We do not enter into derivative transactions for speculative purposes. On December 31, 2012, we did not have any open foreign currency forward exchange contracts. See "Item 5. Operating and Financial Review and Prospects—B. Liquidity and Capital Resources—Currency Forward Sale Exchange Contracts."

Item 12. Description of Securities Other than Equity Securities

A. Debt Securities

Not applicable.

B. Warrants and Rights

Not applicable.

C. Other Securities

Not applicable.

D. American Depository Shares

Not applicable.

PART II

Item 13. Defaults, Dividend Arrearages and Delinquencies

None.

Item 14. Material Modifications to the Rights of Security Holders and Use of Proceeds

Material Modifications to the Rights of Security Holders

We have adopted an Amended and Restated Stockholder Rights Agreement, pursuant to which each of our common shares includes one preferred stock purchase right that entitles the holder to purchase from us a unit consisting of one-thousandth of a share of our Series A Participating Preferred Stock or additional common shares if any third party seeks to acquire control of a substantial block of our common shares without the approval of our board of directors.

Item 15. Controls and Procedures

(a) Disclosure Controls and Procedures

The Company's Chief Executive Officer and the Chief Financial Officer of Ocean Rig AS, the Company's wholly-owned subsidiary, have conducted an evaluation of the effectiveness of the Company's disclosure controls and procedures (as defined in Rule 13a-15(e) and 15d-15(e) of the Exchange Act) as of December 31, 2012. The Company's disclosure controls and procedures are designed to ensure that information required to be disclosed in the reports the Company files under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms and that such information is accumulated and communicated to the Company's management, including the Company's Chief Executive Officer and the Chief Financial Officer of Ocean Rig AS, to allow for timely decisions regarding required disclosures.

Based on this evaluation, the Company's Chief Executive Officer and the Chief Financial Officer of Ocean Rig AS concluded that, as of December 31, 2012, the Company's disclosure controls and procedures are effective to provide reasonable assurance that the information required to be disclosed by us in reports filed under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms.

(b) Management's Annual Report on Internal Control Over Financial Reporting

Internal control over financial reporting refers to the process designed by, or under the supervision of our Chief Executive Officer and the Chief Financial Officer of Ocean Rig AS and effected by our board of directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles and includes those policies and procedures that:

Pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company;

Provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and directors of the Company; and

Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company's assets that could have a material effect on the financial statements.

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Under the supervision and with the participation of our management, including our Chief Executive Officer and the Chief Financial Officer of Ocean Rig AS, our wholly-owned subsidiary, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in "Internal Control—Integrated Framework" issued by the Committee of Sponsoring Organizations of the Treadway Commission, or the COSO, as of December 31, 2012.

Internal control over financial reporting cannot provide absolute assurance of achieving financial reporting objectives because of its inherent limitations. Internal control over financial reporting is a process that involves human diligence and compliance and is subject to lapses in judgment and breakdowns resulting from human failures. Internal control over financial reporting also can be circumvented by collusion or improper override. Because of such limitations, there is a risk that material misstatements may not be prevented or detected on a timely basis by internal control over financial reporting. However, these inherent limitations are known features of the financial reporting process and it is possible to design into the process safeguards to reduce, though not eliminate, this risk.

Management has assessed the effectiveness of the Company's internal control over financial reporting at December 31, 2012, based on the framework established in "Internal Control — Integrated Framework" issued by the COSO. Based on the aforementioned assessment, management concluded that the Company's internal control over financial reporting was effective as of December 31, 2012.

The independent registered public accounting firm, Ernst Young (Hellas) Certified Auditors Accountants S.A., that audited the consolidated financial statements of the Company for the year ended December 31, 2012, included in this annual report, has issued an attestation report on the Company's internal control over financial reporting.

The report of Ernst Young (Hellas) Certified Auditors Accountants S.A. included in "Item 18. Financial Statements" of this annual report is incorporated herein by reference.

(d) Changes in Internal Control over Financial Reporting

There have been no significant changes in our internal control over financial reporting that have occurred during the year ended December 31, 2012 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Item 16A. Audit Committee Financial Expert

Our board of directors has determined that Mr. Prokopios (Akis) Tsirigakis, whose biographical details are included in "Item. 6 Directors, Senior Management and Employees—A. Directors and Senior Management," a member of our audit committee, qualifies as an "audit committee financial expert," as such term is defined in Item 407 of Regulation S-K promulgated by the SEC and Form 20-F. Our board of directors has also determined that Mr. Tsirigakis is independent under SEC Rule 10A-3 of the Exchange Act and the independence rules of the NASDAQ Stock Market.

Item 16B. Code of Ethics

We have adopted a code of ethics that applies to our directors, officers, employees and agents. We will provide a hard copy of our code of ethics free of charge upon written request of a shareholder. Shareholders may direct their requests to the attention of Corporate Secretary, Ocean Rig UDW Inc., 10 Skopa Street, Tribune House, 2nd Floor, Office 202, CY 1075, Nicosia, Cyprus. No substantive amendments were made to our code of ethics during the fiscal year ended December 31, 2012, and no waivers of our code of ethics were granted to our principal executive officer, principal financial officer, principal accounting officer or controller or persons performing similar functions during the fiscal year ended December 31, 2012.

Item 16C. Principal Accountant Fees and Services

Our independent auditors have billed us for audit, audit-related and non-audit services for the years ended December 31, 2012 and 2011. The fees billed are set forth as follows:

	2011		2012
	(U.S. Dollars in thousands)


Audit fees	$	1,591	$	751
Audit-related fees		-		-
Tax fees		75		179
All other fees		-		-

Total fees	$	1,666	$	930

There were no audit-related or other fees billed in 2012 or 2011. Audit fees represent professional services rendered for the audit of our annual financial statements and services provided by the principal accountant in connection with statutory and regulatory filings or engagements. Taxation fees represent fees for professional services rendered by the principal accountant for tax compliance, tax advice and tax planning.

All audit and non-audit services, including services described above were pre-approved by the audit committee. Our audit committee is responsible for the appointment, retention, compensation, evaluation and oversight of the work of the independent auditors. As part of this responsibility, our audit committee pre-approves the audit and non-audit services performed by the independent auditors in order to assure that they do not impair the auditors' independence from the Company. The audit committee has adopted a policy which sets forth the procedures and the conditions pursuant to which services proposed to be performed by the independent auditors may be pre-approved.

Item 16D. Exemptions from the Listing Standards for Audit Committees

Not applicable.

Item 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers

On December 6, 2011, we announced that our board of directors had approved a repurchase program for up to a total of $500.0 million of our common shares and 9.5% senior unsecured notes due 2016. Our common shares and unsecured notes may be purchased under the program from time to time through December 31, 2013. Purchases made by us will be made for cash in open market transactions at prevailing market prices or in privately negotiated transactions. The timing and amount of purchases under the program are determined by our management based on market conditions and other factors. We are not required to purchase any specific number or amount of common shares or unsecured notes under the program and the program may be suspended without our having purchased any common shares or unsecured notes or reinstated at any time in our discretion and without notice.

As of December 31, 2012, we had not purchased any common shares under the program described above.

In addition, companies affiliated with our Chairman, President and Chief Executive Officer purchased an aggregate of 2,185,000 of our common shares in the public offering of common shares held by DryShips that was completed on April 17, 2012 at the public offering price of $16.25.

Item 16F Change in Registrant's Certifying Accountant

None.

Item 16G. Corporate Governance

As a foreign private issuer, we are subject to less stringent corporate governance requirements than U.S.-domiciled companies. Subject to certain exceptions, NASDAQ permits foreign private issuers to follow home country practice in lieu of the NASDAQ corporate governance requirements. The practices we intend to follow in lieu of NASDAQ's corporate governance rules are:

●

In lieu of obtaining shareholder approval prior to the issuance of designated securities or the adoption of equity compensation plans or material amendments to such equity compensation plans, we will comply with provisions of the BCA, providing that the board of directors approves share issuances and adoptions of and material amendments to equity compensation plans.

●

Our board of directors will not hold regularly scheduled meetings at which only independent directors are present.

●

As a foreign private issuer, we are not required to solicit proxies or provide proxy statements to NASDAQ pursuant to NASDAQ corporate governance rules or Marshall Islands law. Consistent with Marshall Islands law and as provided in our bylaws, we will notify our shareholders of meetings between 15 and 60 days before the meeting. This notification will contain, among other things, information regarding business to be transacted at the meeting. In addition, our bylaws provide that shareholders must give us between 150 and 180 days advance notice to properly introduce any business at a meeting of shareholders.

Item 16H. Mine Safety Disclosure

Not applicable.

PART III

Item 17. Financial Statements

See "Item 18. Financial Statements."

Item 18. Financial Statements

The financial statements beginning on page F-1 together with the respective reports of the Independent Registered Public Accounting firms therefore, are filed as a part of this annual report.

Item 18.1 Schedule I - Condensed Financial Information of Ocean Rig UDW Inc. (Parent Company Only)

The Schedule I, beginning after page F-39, is filed as part of this report.

Item 19. Exhibits

Exhibit Number		Description

1.1		Second Amended and Restated Articles of Incorporation of Ocean Rig UDW Inc., incorporated by reference to exhibit 3.1 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

1.2		Second Amended and Restated Bylaws of Ocean Rig UDW Inc., incorporated by reference to exhibit 3.2 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

1.3		Certificate of Designations of Rights, Preferences and Privileges of Series A Participating Preferred Stock of Ocean Rig UDW Inc., incorporated by reference to exhibit 4.3 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

2.1		Form of Stock Certificate, incorporated by reference to exhibit 4.1 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 17, 2011.

2.2		Amended and Restated Stockholder Rights Agreement, dated June 3, 2011, incorporated by reference to exhibit 4.2 to the Registration Statement on Form F-4/A of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

2.3		Bond Agreement between Ocean Rig UDW Inc. and Norsk Tillitsmann ASA, dated April 14, 2011, incorporated by reference to exhibit 10.40 of the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940) filed with the SEC on August 1, 2011.

2.4		Indenture, dated as of September 20, 2012, by and among Drill Rigs Holdings Inc., Ocean Rig UDW Inc., and each of the Guarantors party thereto, U.S. Bank National Association, as Trustee, and Deutsche Bank Trust Company Americas, as Noteholder Collateral Agent, Registrar and Paying Agent, relating to 6.50% Senior Secured Notes Due 2017.

2.5		Supplemental Indenture, dated as of January 23, 2013, by and among Drill Rigs Holdings Inc., Ocean Rig UDW Inc., as Guarantor, the other Guarantors, and U.S. Bank National Association, as Trustee, amending and supplementing the Indenture, dated as of September 20, 2012, by and among Drill Rigs Holdings Inc., Ocean Rig UDW Inc., and each of the Guarantors party thereto, U.S. Bank National Association, as Trustee, and Deutsche Bank Trust Company Americas, as Noteholder Collateral Agent, Registrar and Paying Agent, relating to 6.50% Senior Secured Notes Due 2017.

2.6		Second Supplemental Indenture, dated as of January 30, 2013, amending and supplementing the Indenture, dated as of September 20, 2012, as amended by a supplemental indenture, dated as of January 23, 2013, by and among Drill Rigs Holdings Inc., Ocean Rig UDW Inc., and each of the Guarantors party thereto, U.S. Bank National Association, as Trustee, and Deutsche Bank Trust Company Americas, as Noteholder Collateral Agent, Registrar and Paying Agent, relating to 6.50% Senior Secured Notes Due 2017.

2.7		Third Supplemental Indenture, dated as of March 15, 2013, amending and supplementing the Indenture, dated as of September 20, 2012, as amended by a supplemental indenture, dated as of January 23, 2013, and a second supplemental indenture, dated as of January 30, 2013, by and among Drill Rigs Holdings Inc., Ocean Rig UDW Inc., and each of the Guarantors party thereto, U.S. Bank National Association, as Trustee, and Deutsche Bank Trust Company Americas, as Noteholder Collateral Agent, Registrar and Paying Agent, relating to 6.50% Senior Secured Notes Due 2017.
4.1		Drillship Master Agreement between DryShips Inc. and Samsung Heavy Industries Co., Ltd., incorporated by reference to exhibit 10.1 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

4.2		Novation Agreement between Samsung Heavy Industries Co., Ltd., DryShips Inc. and Ocean Rig UDW Inc., incorporated by reference to exhibit 10.2 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

4.3		Addendum No. 1 dated May 16, 2011 to a Drillship Master Agreement, dated November 22, 2010, between DryShips Inc. and Samsung Heavy Industries Co., Ltd., as novated by a Novation Agreement, dated December 30, 2010, between Samsung Heavy Industries Co., Ltd., DryShips Inc. and Ocean Rig UDW Inc., incorporated by reference to exhibit 10.3 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

4.4		Addendum No. 2 dated January 27, 2012 to a Drillship Master Agreement, dated November 22, 2010, between DryShips Inc. and Samsung Heavy Industries Co., Ltd., as novated by a Novation Agreement, dated December 30, 2010 and as amended, incorporated by reference to exhibit 4.4 to the Annual Report on Form 20-F of Ocean Rig UDW Inc. for the fiscal year ended December 31, 2011, filed with the SEC on March 14, 2012.

4.5		Addendum No. 3 dated April 2, 2012, to a Drillship Master Agreement, dated November 22, 2010, between DryShips Inc. and Samsung Heavy Industries Co., Ltd., as novated by a Novation Agreement, dated December 30, 2010, and as amended.

4.6		Addendum No. 4, dated September 3, 2012, to a Drillship Master Agreement, dated November 22, 2010, between DryShips Inc. and Samsung Heavy Industries Co., Ltd., as novated by a Novation Agreement, dated December 30, 2010, and as amended.

4.7		Senior Secured Credit Facility Agreement, dated April 15, 2011, by and among Drillships Holdings Inc., as Borrower, the banks and financial institutions named therein, as Mandated Lead Arrangers and Lenders, and Nordea Bank Finland plc, London Branch, as Agent, relating to a credit facility of $800,000,000, incorporated by reference to exhibit 10.4 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

4.8		Amendment Agreement, dated May 9, 2012, to the Senior Secured Credit Facility Agreement, dated April 15, 2011, by and among Drillships Holdings Inc., as Borrower, the banks and financial institutions named therein, as Mandated Lead Arrangers and Lenders, and Nordea Bank Finland plc, London Branch, as Agent, relating to a credit facility of $800,000,000.

4.9		Addendum No. 2, dated May 18, 2012, to an Amended and Restated Guarantee, Revolving Credit and Term Loan Facility Agreement, dated November 19, 2009, by and among Ocean Rig ASA, Ocean Rig Norway AS and Drill Rigs Holdings Inc., as borrowers, the guarantors listed therein, as original guarantors, the financial institutions listed therein, as banks, DNB Bank ASA, as guarantee bank, DNB Bank ASA, as mandated lead arranger and bookrunner, HSH Nordbank AG, Nordea Bank Norge ASA and Skandinaviska Enskilda Banken AB (Publ), as mandated lead arrangers, and DNB Bank ASA, as agent, for $1,040,000,000.

4.10		Credit Facility Agreement, dated July 18, 2008, by and between Drillship Skopelos Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Dexia Credit Local, New York Branch, as Joint Mandated Lead Arranger, the various financial institutions listed therein, as Lenders, Deutsche Bank AG, London Branch and Dexia Credit Local, New York Branch, as Swap Banks, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.18 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.


4.11		Credit Facility Agreement, dated July 18, 2008, by and between Drillship Kithira Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Dexia Credit Local, New York Branch, as Joint Mandated Lead Arranger, the various financial institutions listed therein, as Lenders, Deutsche Bank AG, London Branch and Dexia Credit Local, New York Branch, as Swap Banks, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.19 of the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

4.12		Supplemental Agreement, dated September 17, 2008, by and between Drillship Skopelos Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Dexia Credit Local, New York Branch, as Joint Mandated Lead Arranger, Deutsche Bank AG, London Branch and Dexia Credit Local, New York Branch, as Swap Banks, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, incorporated by reference to Exhibit 4.51 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2009, filed with the SEC on April 9, 2010.

4.13		Supplemental Agreement, dated September 17, 2008, relating to a Credit Facility Agreement, dated July 18, 2008, by and between Drillship Kithira Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Dexia Credit Local, New York Branch, as Joint Mandated Lead Arranger, Deutsche Bank AG, London Branch and Dexia Credit Local, New York Branch, as Swap Banks, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, incorporated by reference to Exhibit 4.52 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2009, filed with the SEC on April 9, 2010.

4.14		Supplemental Agreement No. 2, dated December 18, 2008, by and between Drillship Skopelos Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Dexia Credit Local, New York Branch, as Joint Mandated Lead Arranger, Deutsche Bank AG, London Branch and Dexia Credit Local, New York Branch, as Swap Banks, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, as amended and supplemented by a Supplemental Agreement dated September 17, 2008, incorporated by reference to Exhibit 4.53 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2009, filed with the SEC on April 9, 2010.

4.15		Supplemental Agreement No. 2, dated December 18, 2008, relating to a Credit Facility Agreement, dated July 18, 2008, by and between Drillship Kithira Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Dexia Credit Local, New York Branch, as Joint Mandated Lead Arranger, Deutsche Bank AG, London Branch and Dexia Credit Local, New York Branch, as Swap Banks, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, as amended and supplemented by a Supplemental Agreement dated September 17, 2008, incorporated by reference to Exhibit 4.54 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2009, filed with the SEC on April 9, 2010.

4.16		Waiver Letter, dated May 21, 2009, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, as amended and supplemented by the supplemental agreement dated September 17, 2008 and the supplemental agreement No. 2 dated December 18, 2008, by and among (among others) Drillship Skopelos Owners Inc., as Owner, the Lenders under the Credit Agreement, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to Exhibit 4.78 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2010, filed with the SEC on April 15, 2011.

4.17		Waiver Letter, dated May 21, 2009, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, as amended and supplemented by the supplemental agreement dated September 17, 2008 and the supplemental agreement No. 2 dated December 18, 2008, by and among (among others) Drillship Kithira Owners Inc., as Owner, the Lenders under the Credit Agreement, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to Exhibit 4.79 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2010, filed with the SEC on April 15, 2011.


4.18		Facility Agent's and Security Trustee's Consent Letter, dated June 5, 2009, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, as amended and supplemented by the supplemental agreement dated September 17, 2008 and the supplemental agreement No. 2 dated December 18, 2008, by and among (among others) Drillship Skopelos Owners Inc., as Owner, the Lenders under the Credit Agreement, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to Exhibit 4.80 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 310, 2010, filed with the SEC on April 15, 2011.

4.19		Facility Agent's and Security Trustee's Consent Letter, dated June 5, 2009, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, as amended and supplemented by the supplemental agreement dated September 17, 2008 and the supplemental agreement No. 2 dated December 18, 2008, by and among (among others) Drillship Kithira Owners Inc., as Owner, the Lenders under the Credit Agreement, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to Exhibit 4.81 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2010, filed with the SEC on April 15, 2011.

4.20		Supplemental Agreement No. 3, dated January 29, 2010, by and among Drillship Skopelos Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Dexia Credit Local, New York Branch, as Joint Mandated Lead Arranger, Deutsche Bank AG, London Branch and Dexia Credit Local, New York Branch, as Swap Banks, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, relating to $562,500,000 Credit Facility Agreement as amended and supplemented by a Supplemental Agreement dated September 17, 2008 and a Supplemental Agreement No. 2 dated December 18, 2008, incorporated by reference to Exhibit 4.55 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2009, filed with the SEC on April 9, 2010.

4.21		Supplemental Agreement No. 3, dated January 29, 2010, by and among Drillship Kithira Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Dexia Credit Local, New York Branch, as Joint Mandated Lead Arranger, Deutsche Bank AG, London Branch and Dexia Credit Local, New York Branch, as Swap Banks, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, relating to $562,500,000 Credit Facility Agreement as amended and supplemented by a Supplemental Agreement dated September 17, 2008 and a Supplemental Agreement No. 2 dated December 18, 2008, incorporated by reference to Exhibit 4.56 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2009, filed with the SEC on April 9, 2010.

4.22		Facility Agent's Consent Letter, dated June 23, 2010 relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, as amended and supplemented by the supplemental agreement dated September 17, 2008, the supplemental agreement no. 2 dated December 18, 2008 and the supplemental agreement no. 3 dated January 29, 2010, by and between (among others) Drillship Skopelos Owners Inc., as Owner, certain Lenders referred to therein, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to Exhibit 4.84 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2010, filed with the SEC on April 15, 2011.

4.23		Facility Agent's Consent Letter, dated June 23, 2010, relating to a $562,500,000 Credit Facility Agreement, dated July 18, 2008, as amended and supplemented by the supplemental agreement dated September 17, 2008, the supplemental agreement no. 2 dated December 18, 2008 and the supplemental agreement no. 3 dated January 29, 2010, by and between (among others) Drillship Kithira Owners Inc., as Owner, certain Lenders referred to therein, Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to Exhibit 4.85 to the Annual Report on Form 20-F of DryShips Inc. for the fiscal year ended December 31, 2010, filed with the SEC on April 15, 2011.

4.24		Amendment and Restatement Agreement to the Credit Agreement, dated April 27, 2011, by and among Drillship Skopelos Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Deutsche Bank AG, London Branch, as Swap Bank, Deutsche Bank Luxembourg S.A., as Facility Agent for itself and on behalf of the various financial institutions as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.32 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.


4.25		Amendment and Restatement Agreement to the Credit Agreement, dated April 27, 2011, by and among Drillship Kithira Owners Inc., as Owner, Deutsche Bank A.G., London Branch, as Bookrunner and Joint Mandated Lead Arranger, Deutsche Bank AG, London Branch, as Swap Bank, Deutsche Bank Luxembourg S.A., as Facility Agent for itself and on behalf of the various financial institutions as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.33 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

4.26		Amendment Agreement to the Credit Agreement, dated August 10, 2011, by and among Drillship Skopelos Owners Inc., as Owner, DryShips Inc., as Sponsor and Ocean Rig UDW Inc., as Ocean Rig guarantor, Deutshce Bank AG, London Branch, as Bookrunner and Mandated Lead Arranger, Deutsche Bank AG, London Branch, as Swap Bank, Deutsche Bank Luxembourg S.A., as Facility Agent for itself and on behalf of various financial institutions as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.34 to the Registration Statement on Form F-4/A of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 17, 2011.

4.27		Sponsor Construction and Post-Delivery Guarantee, dated July 18, 2008, between DryShips Inc., as Guarantor, Deutsche Bank Luxembourg S.A., as Facility Agent, various financial institutions, as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.34 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940), filed with the SEC on August 1, 2011.

4.28		Sponsor Construction and Post-Delivery Guarantee, dated July 18, 2008, between DryShips Inc., as Guarantor, Deutsche Bank Luxembourg S.A., as Facility Agent, various financial institutions, as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.35 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940) filed with the SEC on August 1, 2011.

4.29		Ocean Rig Guarantee, dated April 27, 2011, between Ocean Rig UDW Inc., as Guarantor, Deutsche Bank Luxembourg S.A., as Facility Agent for itself and on behalf of various financial institutions as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.36 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940) filed with the SEC on August 1, 2011.

4.30	Ocean Rig Guarantee, dated April 27, 2011, between Ocean Rig UDW Inc., as Guarantor, Deutsche Bank Luxembourg S.A., as Facility Agent for itself and on behalf of various financial institutions as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, incorporated by reference to exhibit 10.37 to the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940) filed with the SEC on August 1, 2011.

4.31	Credit Facility Agreement, dated July 18, 2008, by and among Drillship Skopelos Owners Inc., as Owner, Deutsche Bank AG, London Branch, as Bookrunner and Mandated Lead Arranger, various financial institutions, as Lenders, Deutsche Bank AG, London Branch, as Swap Bank, and Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, as amended and supplemented from time to time and most recently amended and restated on May 14, 2012.

4.32	Credit Facility Agreement, dated July 18, 2008, by and among Drillship Kithira Owners Inc., as Owner, Deutsche Bank AG, London Branch, as Bookrunner and Mandated Lead Arranger, various financial institutions, as Lenders, Deutsche Bank AG, London Branch, as Swap Bank, and Deutsche Bank Luxembourg S.A., as Facility Agent, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee, as amended and supplemented from time to time and most recently amended and restated on May 14, 2012.

4.33	Sponsor Guarantee, dated May 14, 2012, between DryShips Inc., as Guarantor, Deutsche Bank Luxembourg S.A., as Facility Agent for itself and on behalf of various financial institutions, as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee.


4.34	Sponsor Guarantee, dated May 14, 2012, between DryShips Inc., as Guarantor, Deutsche Bank Luxembourg S.A., as Facility Agent for itself and on behalf of various financial institutions, as Lenders, and Deutsche Bank AG Filiale Deutschlandgeschaft, as Security Trustee.

4.35	Deed of Release and Amendment, dated May 14, 2012, by and among Drillship Skopelos Owners Inc., as Owner, Ocean Rig Drilling Operations B.V., as Bareboat Charterer, DryShips Inc., as Sponsor, Ocean Rig UDW Inc., Drillships Investment Inc., Skopelos Shareholders Inc., Deutsche Bank AG, London Branch, as Swap Bank, Deutsche Bank Luxembourg S.A., as Facility Agent on behalf of various financial institutions as Lenders, Deutsche Bank AG Filiale Deutschlandgescharft, as Security Trustee, Deutshce Bank AG, London Branch, as Bookrunner and Mandated Lead Arranger, and Deutsche Bank AG, London Branch, as Account Bank.

4.36	Deed of Release and Amendment, dated May 14, 2012, by and among Drillship Kithira Owners Inc., as Owner, Ocean Rig Poseidon Operations Inc., as Bareboat Charterer, DryShips Inc., as Sponsor, Ocean Rig UDW Inc., Drillships Investment Inc., Kithira Shareholders Inc., Deutsche Bank AG, London Branch, as Swap Bank, Deutsche Bank Luxembourg S.A., as Facility Agent on behalf of various financial institutions as Lenders, Deutsche Bank AG Filiale Deutschlandgescharft, as Security Trustee, Deutshce Bank AG, London Branch, as Bookrunner and Mandated Lead Arranger, and Deutsche Bank AG, London Branch, as Account Bank.

4.37	Global Services Agreement, dated December 1, 2010, by and between DryShips Inc. and Cardiff Marine Inc., incorporated by reference to exhibit 10.38 of the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940) filed with the SEC on August 1, 2011.

4.38	Termination Agreement, effective January 1, 2013, by and between DryShips Inc. and Cardiff Marine Inc., relating to the Global Services Agreement, dated December 1, 2010, by and between DryShips Inc. and Cardiff Marine Inc.

4.39	Services Agreement, effective January 1, 2013, by and between Ocean Rig Management Inc. and Cardiff Drilling Inc.

4.40	Consultancy Agreement, dated September 1, 2010, by and between DryShips Inc. and Vivid Finance Limited, incorporated by reference to exhibit 10.39 of the Registration Statement on Form F-4 of Ocean Rig UDW Inc. (Registration No. 333-175940) filed with the SEC on August 1, 2011.

4.41	Addendum No. 1, effective January 1, 2013, to the Consultancy Agreement, dated September 1, 2010, by and between Ocean Rig UDW Inc. and Vivid Finance Inc.

4.42	Consultancy Agreement, effective January 1, 2013, by and between Ocean Rig Management Inc. and Vivid Finance Limited.

4.43	Registration Rights Agreement, dated as of March 20, 2012, by and between DryShips Inc. and Ocean Rig UDW Inc., incorporated by reference to exhibit 4.4 to the Registration Statement on Form F-1 of Ocean Rig UDW Inc. (Registration No. 333-180241), filed with the SEC on March 20, 2012.

4.44	Facilities Agreement, dated February 28, 2013, by and among Drillships Ocean Ventures Inc., as Borrower, and Ocean Rig UDW Inc., as Parent and Guarantor, and the companies listed therein, as Guarantors, and the banks and financial institutions named therein, as Mandated Lead Arrangers, with the banks and financial institutions named therein, as Lenders under the Commercial Facilities, Eksportkreditt Norge AS, as Lender under the Eksportkreditt/GEIK Facilities, The Export-Import Bank of Korea, as Lender under the Kexim Facilities, and DNB Bank ASA, as Facility Agent and Security Agent, relating to $1,350,000,000 of Term Loan Facilities.

8.1	Subsidiaries of Ocean Rig UDW Inc.

12.1	Rule 13a-14(a)/15d-14(a) Certification of Principal Executive Officer.

12.2	Rule 13a-14(a)/15d-14(a) Certification of Principal Financial Officer.


13.1	Certification of Principal Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

13.2	Certification of Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

15.1	Consent of Independent Registered Public Accounting Firm

15.2	Consent of Independent Registered Public Accounting Firm

101	The following financial information from Ocean Rig UDW Inc.'s Annual Report on Form 20-F for the fiscal year ended December 31, 2012, formatted in Extensible Business Reporting Language (XBRL): (1) Consolidated Balance Sheets as of December 31, 2011 and 2012; (2) Consolidated Statements of Operations for the years ended December 31, 2010, 2011 and 2012; (3) Consolidated Statements of Comprehensive Income for the years ended December 31, 2010, 2011 and 2012; (4) Consolidated Statements of Stockholders' Equity for the years ended December 31, 2010, 2011 and 2012; (5) Consolidated Statements of Cash Flows for the years ended December 31, 2010, 2011 and 2012; and (6) Notes to Consolidated Financial Statements.

SIGNATURES

The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized the undersigned to sign this annual report on its behalf.

	OCEAN RIG UDW INC.



	By:	/s/ George Economou
	Name:	George Economou
	Title:	Chairman, President and
		Chief Executive Officer

Dated: March 21, 2013

OCEAN RIG UDW INC.

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS


			Page


Report of Independent Registered Public Accounting Firm (Ernst & Young (Hellas) Certified Auditors Accountants S.A.)	F-2
Report of Independent Registered Public Accounting Firm on Internal Control Over Financial Reporting (Ernst & Young (Hellas) Certified Auditors Accountants S.A.)	F-3
Report of Independent Registered Public Accounting Firm (Ernst & Young AS)	F-4
Consolidated Balance Sheets as of December 31, 2011 and 2012	F-5
Consolidated Statements of Operations for the years ended December 31, 2010, 2011 and 2012	F-6
Consolidated Statements of Comprehensive Income/(Loss) for the years ended December 31, 2010, 2011 and 2012	F-7
Consolidated Statements of Stockholders' Equity for the years ended December 31, 2010, 2011 and 2012	F-8
Consolidated Statements of Cash Flows for the years ended December 31, 2010, 2011 and 2012	F-9
Notes to Consolidated Financial Statements	F-10

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Shareholders of Ocean Rig UDW Inc.

We have audited the accompanying consolidated balance sheets of Ocean Rig UDW Inc. as of December 31, 2012 and 2011, and the related consolidated statements of operations, comprehensive income/(loss), stockholders' equity, and cash flows for each of the two years in the period ended December 31, 2012. Our audits also included the financial statement schedule listed in Item 18.1. These financial statements and schedule are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and schedule based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated financial position of Ocean Rig UDW Inc. at December 31, 2012 and 2011, and the consolidated results of its operations and its cash flows for each of the two years in the period ended December 31, 2012, in conformity with U.S. generally accepted accounting principles. Also, in our opinion, the related financial statement schedule, when considered in relation to the basic financial statements taken as a whole, presents fairly in all material respects the information set forth therein.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), Ocean Rig UDW Inc.'s internal control over financial reporting as of December 31, 2012, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated March 21, 2013 expressed an unqualified opinion thereon.

/s/ Ernst & Young (Hellas) Certified Auditors Accountants S.A.

Athens, Greece

March 21, 2013

F-2

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM ON INTERNAL CONTROL OVER FINANCIAL REPORTING

The Board of Directors and Shareholders of Ocean Rig UDW Inc.

We have audited Ocean Rig UDW Inc.'s internal control over financial reporting as of December 31, 2012, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (the COSO criteria). Ocean Rig UDW Inc.'s management is responsible for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management's Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the company's internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, Ocean Rig UDW Inc. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2012, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Ocean Rig UDW Inc. as of December 31, 2012 and 2011 and the related consolidated statements of operations, comprehensive income/(loss), stockholders' equity and cash flows for each of the two years in the period ended December 31, 2012 of Ocean Rig UDW Inc. and the financial statement schedule listed in Item 18.1 and our report dated March 21, 2013 expressed an unqualified opinion thereon.

/s/ Ernst & Young (Hellas) Certified Auditors Accountants S.A.

Athens, Greece

March 21, 2013

F-3

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Shareholders of Ocean Rig UDW Inc.

We have audited the accompanying consolidated statements of operations, comprehensive income, stockholders' equity and cash flows of Ocean Rig UDW Inc. ("the Company") for the year ended December 31, 2010. Our audit also included the financial statement schedule listed in Item 18.1. These financial statements and schedule are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and schedule based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. We were not engaged to perform an audit of the Company's internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the consolidated results of Ocean Rig UDW Inc.'s operations and its cash flows for the year ended December 31, 2010, in conformity with U.S. generally accepted accounting principles. Also, in our opinion, the related financial statement schedule, when considered in relation to the basic financial statements taken as a whole, presents fairly in all material respects the information set forth therein.

/s/ Ernst & Young AS

Stavanger, Norway

April 29, 2011 (except for the effects of the restatement discussed in the second paragraph of Note 2(d) to the consolidated financial statements and the financial statement schedule listed in Item 18.1, as to which the date is March 13, 2012)

F-4

OCEAN RIG UDW INC.

Consolidated Balance Sheets

As of December 31, 2011 and 2012

(Expressed in thousands of U.S. Dollars - except for share and per share data)

	December 31, 2011			December 31, 2012
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	250,878		$	317,366
Restricted cash (Note 2)		57,060			37,321
Trade accounts receivable, net of allowance for doubtful receivables of $18,420 and $14,685.		123,223			148,808
Other current assets (Note 4)		65,248			93,639
Total current assets		496,409			597,134

FIXED ASSETS, NET:
Advances for drillships under construction (Note 5)		754,925			992,825
Drilling rigs, drillships, machinery and equipment, net (Note 6)		4,538,838			4,399,462
Total fixed assets, net		5,293,763			5,392,287

OTHER NON-CURRENT ASSETS:
Restricted cash (Note 2)		125,040			155,374
Financial instruments (Note 10)		-			935
Intangible assets, net (Note 7)		9,062			7,619
Other non-current assets (Note 8)		91,081			71,765
Total non-current assets, net		225,183			235,693
Total assets	$	6,015,355		$	6,225,114

LIABILITIES AND STOCKHOLDERS' EQUITY

CURRENT LIABILITIES:
Current portion of long-term debt (Note 9)	$	210,166		$	169,780
Accounts payable and other current liabilities		37,305			69,827
Accrued liabilities		104,633			156,886
Deferred revenue		34,726			69,635
Financial instruments (Note 10)		40,727			39,537
Total current liabilities		427,557			505,665

NON-CURRENT LIABILITIES
Long term debt, net of current portion (Note 9)		2,525,599			2,683,630
Financial instruments (Note 10)		52,025			38,087
Deferred revenue		9,172			71,815
Pensions (Note 11)		2,546			4,057
Other non-current liabilities		-			13,345
Total non-current liabilities		2,589,342			2,810,934

COMMITMENTS AND CONTINGENCIES (Note 17)		-				-

STOCKHOLDERS' EQUITY:
Preferred stock, $0.01 par value; 500,000,000 shares authorized at December 31, 2011 and 2012, nil issued and outstanding at December 31, 2011and 2012, respectively		-				-
Common stock, $0,01par value; 1,000,000,000 shares authorized, at December 31, 2011 and 2012, 131,696,928 and 131,725,128 issued and outstanding at December 31, 2011 and 2012, respectively (Note 12)		1,317			1,317
Additional paid-in capital		3,469,924			3,489,018
Accumulated other comprehensive loss (Note 13)		(51,126	)		(27,825	)
Accumulated deficit		(421,659	)		(553,995	)
Total stockholders' equity		2,998,456			2,908,515
Total liabilities and stockholders' equity	$	6,015,355		$	6,225,114

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

F-5

OCEAN RIG UDW INC.

Consolidated Statements of Operations

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of U.S. Dollars - except for share and per share data)

		Year Ended December 31,
		2010			2011			2012
REVENUES:
Leasing revenue	$	141,211		$	112,118		$	-
Service revenue (including amortization of above market acquired drilling contracts), net		264,501			587,531			941,903
Total Revenues		405,712			699,649			941,903

EXPENSES:
Drilling rigs and drillships operating expenses		119,369			281,833			563,583
Depreciation and amortization		75,092			162,532			224,479
Loss on disposals		1,458			754			133
General and administrative expenses		20,566			46,718			83,647
Legal settlements and other, net (Note 17)		-			-			4,524
Operating income		189,227			207,812			65,537

OTHER INCOME / (EXPENSES):
Interest and finance costs (Note 14)		(8,418	)		(63,752)			(116,427)
Interest income		12,464			9,810			553
Loss on interest rate swaps (Note 10)		(40,303)			(33,455)			(36,974)
Other, net		2,227			2,311			(1,068)
Total other income/(expenses), net		(34,030	)		(85,086)			(153,916)

INCOME / (LOSS) BEFORE INCOME TAXES		155,197			122,726			(88,379)
Income taxes (Note 15)		(20,436	)		(27,428	)		(43,957)

NET INCOME / (LOSS)	$	134,761		$	95,298		$	(132,336)

EARNINGS/ (LOSS) PER SHARE, BASIC AND DILUTED	$	1.30		$	0.72		$	(1.00)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES, BASIC AND DILUTED (Note 12)		103,908,279			131,696,928			131,696,935

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

F-6

OCEAN RIG UDW INC.

Consolidated Statements of Comprehensive Income/(Loss)

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of U.S. Dollars - except for share and per share data)

	2010		2011		2012

Net income / (Loss)	$	134,761	$	95,298	$	(132,336)

Other Comprehensive income / (loss):
Unrealized interest rate swap gains/ (losses)		(5,495)		3,272			-
Realized loss on cash flow hedges associated with capitalized interest		(21,523)		(3,272)			-
Reclassification of realized losses associated with capitalized interest to Consolidated Statement of Operations		-		722		1,034
Reclassification of losses on previously designated cash flow hedges to Consolidated Statement of Operations, net		-		9,816		22,904
Actuarial gains/ (losses)		424		(942)		(637)
Other Comprehensive income/ (loss)		(26,594)		9,596		23,301

Total Comprehensive income / (loss)	$	108,167	$	104,894	$	(109,035)

F-7

OCEAN RIG UDW INC.

Consolidated Statements of Stockholders' Equity

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of U.S. Dollars - except for share and per share data)

	Common Stock				Additional Paid-in			Accumulated Other Comprehensive			Accumulated			Total Stockholders'
	Shares		Par Value		Capital			Loss			Deficit			Equity
BALANCE, December 31, 2009		103,125,500	$	10	$	2,386,953		$	(34,128	)	$	(651,718	)	$	1,701,117
Net income		-		-		-			-			134,761			134,761
Other comprehensive loss		-		-		-			(26,594	)		-			(26,594	)
Share dividend		-		1,021		(1,021	)		-			-			-
Private placement		28,571,428		286		488,015			-			-			488,301
Capital contribution from DryShips Inc		-		-		583,497			-			-			583,497

BALANCE, December 31, 2010		131,696,928		1,317		3,457,444			(60,722	)		(516,957	)		2,881,082
Net income		-		-		-			-			95,298			95,298
Other comprehensive income		-		-		-			9,596			-			9,596
Capital contribution from DryShips Inc		-		-		12,480			-			-			12,480
BALANCE, December 31, 2011		131,696,928		1,317		3,469,924			(51,126	)		(421,659	)		2,998,456
Net loss		-		-		-			-			(132,336	)		(132,336	)
Issuance of non-vested shares		28,200		-		-			-			-			-
Amortization of stock based compensation		-		-		613			-			-			613
Other comprehensive income		-		-		-			23,301			-			23,301
Capital contribution from DryShips Inc		-		-		18,481			-			-			18,481
BALANCE, December 31, 2012		131,725,128	$	1,317	$	3,489,018		$	(27,825	)	$	(553,995	)	$	2,908,515

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

F-8

OCEAN RIG UDW INC.

Consolidated Statements of Cash Flows

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of U.S. Dollars – except for share and per share data)

		Years ended December 31,

		2010				2011			2012
Cash Flows from Operating Activities:
Net income/loss		$	134,761		$		95,298		$	(132,336)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization			75,092				162,532			224,479
Loss from disposal of assets			1,458				754			133
Commitments fees on undrawn line of credit			6,375				-			-
Amortization of deferred financing fees			-				17,778			12,944
Net amortization of fair value of acquired drilling contracts			1,222				1,170			-
Amortization of cash flow hedge reserve			(21,523)				9,816			22,904
Interest income on restricted cash related to drillships			(6,205)				(4,318	)		-
Change in fair value of derivatives			33,119				(15,114)			(16,063)
Amortization of stock based compensation			-				-			613
Other non cash items			-				12,817			16,961
Changes in operating assets and liabilities:
Trade accounts receivable			41,200				(98,937	)		(24,040)
Other current and non-current assets			(4,863	)			(48,409	)		(56,938)
Deferred taxes			209				(209	)		-
Accounts payable and other current and non-current liabilities			(9,390	)			28,287			45,867
Pension liability			1,416				1,002			874
Accrued liabilities			5,022				59,002			52,253
Deferred revenue			1,805				3,693			97,552
Security deposits for derivatives			(37,900	)			45,500			33,100
Net Cash Provided by Operating Activities			221,798				270,662			278,303
Cash Flows from Investing Activities:
Advances for drillships under construction			(705,022	)			(1,864,862	)		(212,185)
Down payment for drilling rigs under construction and other improvements			(294,569	)			-			-
Drillship options			(99,024	)			-			-
Drilling rigs, drillships machinery, equipment and other improvements			(6,834	)			(78,480	)		(97,869)
Fixed assets disposal			-				12			180
(Increase) / decrease in restricted cash			(335,898	)			385,011			(10,595)
Rig upgrades			-				(3,182	)		-
Net Cash Used in Investing Activities			(1,441,347	)			(1,561,501	)		(320,469)
Cash Flows from Financing Activities:
Capital contribution by DryShips Inc			540,321				-			-
Net proceeds from the issuance of common shares			488,301				-			-
Proceeds from short/long-term credit facilities, terms loans and senior notes			308,250				2,420,476			800,000
Proceeds from intercompany loan			-				175,500			-
Principal payments and repayments of short/long-term debt			(247,717	)			(926,666	)		(671,667)
Repayment of intercompany loan			-				(175,500	)		-
Payment of financing costs, net			(8,094	)			(47,800	)		(19,679)
Net Cash Provided by Financing Activities			1,081,061				1,446,010			108,654
Net (decrease) / increase in cash and cash equivalents			(138,488	)			155,171			66,488
Cash and cash equivalents at beginning of years			234,195				95,707			250,878
Cash and cash equivalents at end of years	$		95,707			$	250,878		$	317,366

SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid during the years for:
Interest, net of amount capitalized			43,203				32,164			73,219
Income taxes			19,803				23,199			45,450

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

F-9

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

1. Basis of Presentation and General Information:

The accompanying consolidated financial statements include the accounts of Ocean Rig UDW Inc., its subsidiaries and consolidated Variable Interest Entities ("VIEs") (collectively, the "Company," "Ocean Rig UDW" or "Group"). Ocean Rig UDW was formed on December 10, 2007, under the laws of the Republic of the Marshall Islands under the name Primelead Shareholders Inc. The Company was established by DryShips Inc. ("DryShips" or "the Parent") for the purpose of being the holding company of its drilling segment. DryShips is a publicly listed company on the NASDAQ Global Select Market (NASDAQ: DRYS). In 2007, DryShips through its subsidiary, Primelead Limited of Cyprus ("Primelead"), purchased approximately 30% of the shares in Ocean Rig ASA. In 2008, the remaining shares in Ocean Rig ASA were acquired and Ocean Rig ASA was delisted from the Oslo Stock Exchange. Ocean Rig UDW acquired all of the outstanding shares of Primelead in December 2007 in a reverse acquisition transaction under common control, which was accounted for as a pooling of interests. Dryships is currently impacted by the prolonged downturn in the drybulk charter market. The Company, in the preparation of its consolidated financial statements, has considered its relationship to its Parent and any impact its Parent's financial condition might have on its own consolidated financial statements. Based on its assessment, the Company has concluded that there is no impact on the basis of preparation of its consolidated financial statements. On November 24, 2010, Ocean Rig UDW established an office and was registered with the Cyprus Registrar of Companies as an overseas company. On October 6, 2011, the Company's common shares commenced "regular way" trading on the NASDAQ Global Select Market under the ticker symbol "ORIG."

Certain prior period amounts have been reclassified to conform to the current year presentation including: a) the reclassification of part of deferred mobilization expenses and deferred revenue from current assets and current liabilities to non-current assets and non-current liabilities, respectively b) the reclassification of foreign exchange gains/losses in the Statement of operations from "General and administrative expenses" to "Other, net" and c) the reclassification of consultancy fees in the Statement of operations from "Interest and finance costs" to "General and administrative expenses."

The Company's customers are oil and gas exploration and production companies, including major integrated oil companies, independent oil and gas producers and government-owned oil and gas companies. Customers individually accounting for more than 10% of the Company's revenues during the years ended December 31, 2010, 2011 and 2012, were as follows:

	Year ended December 31,

	2010			2011			2012
Customer A		57	%		36	%		-
Customer B		43	%		18	%		49	%
Customer C		-			-			18	%
Customer D		-			33	%		12	%
Customer E		-			13	%		-

The loss of any of these significant customers could have a material adverse effect on the Company's results of operations if they were not replaced by other customers.

2. Significant Accounting Policies:

(a)

Principles of consolidation: The accompanying consolidated financial statements have been prepared in accordance with Generally Accepted Accounting Principles in the United States of America ("US GAAP") and include the accounts and operating results of Ocean Rig UDW., its wholly-owned subsidiaries and its VIEs. As of December 31, 2012, the Company consolidated 100% one VIE for which it is deemed to be the primary beneficiary, i.e. it has a controlling financial interest in this entity. The VIE's total assets and liabilities, as of December 31, 2012, were $25,474 and $26,764 respectively, while total liabilities exceeded total assets by $1,290. A VIE is an entity that in general does not have equity investors with voting rights or that has equity investors that do not provide sufficient financial resources for the entity to support its activities. A controlling financial interest in a VIE is present when a company has the power to direct the activities of a VIE that most significantly impact the entity's economic performance and absorbs a majority of an entity's expected losses, receives a majority of an entity's expected residual returns, or both. All intercompany balances and transactions have been eliminated in consolidation. Where necessary, comparatives have been reclassified to conform to changes in presentation in the current year.

F-10

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

2. Significant Accounting Policies-(continued):

(b) Intangible assets:

The Company's finite-lived acquired intangible assets are amortized on a straight-line basis over their estimated useful lives as follows:

Intangible assets/liabilities		Years
Tradenames		10
Software		10
Fair value of above market acquired drilling contracts		Over remaining contract term
Fair value of below market acquired drilling contracts		Over remaining contract term

In accordance with guidance related to Accounting for the Impairment or Disposal of Long-Lived Assets, the Company evaluates the potential impairment of finite-lived acquired intangible assets when there are indicators of impairment. The finite-lived intangibles are tested for impairment whenever events or changes in circumstances indicate that the carrying amount of any asset may not be recoverable based on estimates of future undiscounted cash flows. In the event of impairment, the asset is written down to its fair value. An impairment loss, if any, is measured as the amount by which the carrying amount of the asset exceeds its fair value. For finite-lived intangible assets, no impairment was recognized during any periods presented.

(c) Use of estimates: The preparation of consolidated financial statements in conformity with US 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 consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

(d) Comprehensive income/(loss): The Company's comprehensive income/(loss) is comprised of net income/(loss), actuarial gains/losses related to the adoption and implementation of Accounting Standard Codification ("ASC") 715, "Compensation-Retirement Benefits", as well as losses in the fair value of the derivatives that qualify for hedge accounting in accordance with ASC 815 "Derivatives and Hedging" and realized gains/losses on cash flow hedges associated with capitalized interest in accordance with ASC 815-30-35-38 "Derivatives and Hedging".

In June 2011, the Financial Accounting Standards Board ("FASB") issued Accounting Standard Update ("ASU") 2011-05, "Comprehensive Income, Presentation of Comprehensive Income (Topic 220)", which revises the manner in which entities present comprehensive income in their financial statements. The amendments in this ASU were adopted by the Company in the December 31, 2011 consolidated financial statements and, as a result, the consolidated financial statements for the year ended December 31, 2010 were revised to include a separate statement of comprehensive income and to exclude the components of other comprehensive income from the statement of stockholders' equity.

(e) Cash and cash equivalents: The Company considers highly liquid investments such as time deposits and certificates of deposit with an original maturity of three months or less to be cash equivalents.

(f) Restricted cash: Restricted cash may include (i) retention accounts which can only be used to fund the loan installments coming due; (ii) minimum liquidity collateral requirements or minimum required cash deposits, as defined in the Company's loan agreements; (iii) taxes withheld from employees and deposited in designated bank accounts; (iv) amounts pledged as collateral for bank guarantees to suppliers and (v) amounts pledged as collateral for credit facilities and swap agreements.

(g) Trade accounts receivable net: The amount shown as accounts receivable, trade, at each balance sheet date, includes receivables from customers for drilling rigs and drillships, net of a allowance for doubtful receivables. At each balance sheet date, all potentially uncollectible accounts are assessed individually for purposes of determining the appropriate allowance for doubtful receivables.

(h) Concentration of credit risk: Financial instruments, which potentially subject the Company to significant concentrations of credit risk, consist principally of cash and cash equivalents; trade accounts receivable and derivative contracts (interest rate swaps and foreign currency contracts). The maximum exposure to loss due to credit risk is the book value at the balance sheet date. The Company places its cash and cash equivalents, consisting mostly of bank deposits, with qualified financial institutions. The Company performs periodic evaluations of the relative credit standing of those financial institutions. The Company is exposed to credit risk in the event of non-performance by counter parties to derivative instruments; however, the Company limits its exposure by diversifying among counter parties. When considered necessary, additional arrangements are put in place to minimize credit risk, such as letters of credit or other forms of payment guarantees. The Company limits its credit risk with trade accounts receivable by performing ongoing credit evaluations of its customers' financial condition and generally does not require collateral for its trade accounts receivable.

F-11

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

2. Significant Accounting Policies-(continued):

(h) Concentration of credit risk-(continued):

The Company has made advances for the construction of drillships to Samsung Heavy Industries Co Ltd ("Samsung"). The ownership of the drillships is transferred from the yard to the Company at delivery. The credit risk of the advances is, to a large extent, reduced through refund guarantees issued by banks. As of December 31, 2012, cumulative installment payments made to Samsung amounted to approximately $879,387 for the four units under construction. These installment payments are, to a large extent, secured with irrevocable letters of guarantee, covering pre-delivery installments if the contract is rescinded in accordance with the terms of the contract. The irrevocable letters of guarantee are issued by financial institutions.

(i) Advances for drillships under construction: This represents amounts expended by the Company in accordance with the terms of the construction contracts for drillships as well as other expenses incurred directly or under a management agreement with a related party in connection with on site supervision. In addition, interest costs incurred during the construction (until the asset is substantially complete and ready for its intended use) are capitalized. The carrying value of drillships under construction represents the accumulated costs at the balance sheet date. Cost components include payments for yard installments and variation orders, commissions to related party, construction supervision, equipment, spare parts, capitalized interest, costs related to first time mobilization and commissioning costs. No charge for depreciation is made until commissioning of the newbuilding has been completed and it is ready for its intended use.

(j) Capitalized interest: Interest expense is capitalized during the construction period of rigs and drillships based on accumulated expenditures for the applicable project at the Company's current rate of borrowing. The amount of interest expense capitalized in an accounting period is determined by applying an interest rate ("the capitalization rate") to the average amount of accumulated expenditures for the asset during the period. The capitalization rates used in an accounting period are based on the rates applicable to borrowings outstanding during the period. The Company does not capitalize amounts in excess of actual interest expense incurred in the period. If the Company's financing plans associate a specific new borrowing with a qualifying asset, the Company uses the rate on that borrowing as the capitalization rate to be applied to that portion of the average accumulated expenditures for the asset that does not exceed the amount of that borrowing. If average accumulated expenditures for the asset exceed the amounts of specific new borrowings associated with the asset, the capitalization rate applied to such excess is a weighted average of the rates applicable to other borrowings of the Company. Capitalized interest expense for the years ended December 31, 2010, 2011 and 2012, amounted to $35,780, $57,761 and $44,951, respectively (Note 14).

(k) Insurance claims: The Company records insurance claim recoveries for insured losses incurred on damages to fixed assets, loss of hire and for insured crew medical expenses under "Other current assets". Insurance claims are recorded, net of any deductible amounts, at the time the Company's fixed assets suffer insured damages or loss due to the drilling unit being wholly or partially deprived of income as a consequence of damage to the unit or when crew medical expenses are incurred, recovery is probable under the related insurance policies and the Company can make an estimate of the amount to be reimbursed following the insurance claim.

(l) Foreign currency translation: The functional currency of the Company is the U.S. Dollar since the Company operates in international drilling markets, and therefore primarily transacts business in U.S. Dollars. The Company's accounting records are maintained in U.S. Dollars. Transactions involving other currencies during the year are converted into U.S. Dollars using the exchange rates in effect at the time of the transactions. At the balance sheet dates, monetary assets and liabilities, which are denominated in other currencies, are translated into U.S. Dollars at the year-end exchange rates. Resulting gains or losses are included in "Other, net" in the accompanying consolidated statements of operations.

(m) Drilling rigs, drillships, machinery and equipment, net:

(i) Drilling rigs and drillships are stated at historical cost less accumulated depreciation. Such costs include the cost of adding or replacing parts of drilling rig or drillship machinery and equipment when the cost is incurred, if the recognition criteria are met. The recognition criteria require that the cost incurred extends the useful life of a drilling rig or drillship. The carrying amounts of those parts that are replaced are written off and the cost of the new parts is capitalized. Depreciation is calculated on a straight- line basis over the useful life of the assets after considering the estimated residual value as follows: bare deck 30 years and other asset parts 5 to 15 years for the drilling rigs and drillships. The residual values of the drilling rigs and drillships are estimated at $35 million and $50 million, respectively.

F-12

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

(ii) IT and office equipment are recorded at cost and are depreciated on a straight-line basis over 5 years.

2. Significant Accounting Policies-(continued):

(n) Fair value of above/below market acquired drilling contracts: In a business combination, the Company identifies assets acquired or liabilities assumed and records all such identified assets or liabilities at fair value. Fair value is determined by reference to market data. Favorable or unfavorable drilling contracts exist when there is a difference between the contracted dayrate and the dayrates prevailing at the acquisition date. The amount to be recorded as an asset or liability at the acquisition date is based on the difference between the then-current fair values of a contract with similar characteristics as the contract assumed and the net present value of future contractual cash flows from the drilling contract assumed. When the present value of the contract assumed is greater than the then-current fair value of such contract, the difference is recorded as "Fair value of above market acquired drilling contracts" When the opposite situation occurs, the difference is recorded as "Fair value of below-market acquired drilling contracts". Such assets and liabilities are amortized as a reduction of or an increase in revenue over the period of the drilling contracts assumed.

(o) Impairment of long-lived assets: The Company reviews for impairment long-lived assets and intangible long-lived assets held and used whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. In this respect, the Company reviews its assets for impairment on a rig by rig and drillship by drillship and asset by asset basis. When the estimate of undiscounted cash flows, excluding interest charges, expected to be generated by the use of the asset is less than its carrying amount, the Company evaluates the asset for impairment loss. The impairment loss is determined by the difference between the carrying amount of the asset and the fair value of the asset. The Company evaluates the carrying amounts of its drilling rigs and drillships by obtaining independent appraisals to determine if events have occurred that would require modification to their carrying values or useful lives. In evaluating useful lives and carrying values of long-lived assets, the Company reviews certain indicators of potential impairment, such as undiscounted projected operating cash flows, drilling rig/drillships sales and purchases, business plans and overall market conditions. In developing estimates of future undiscounted cash flows, the Company makes assumptions and estimates about the drilling rigs and drillships future performance, with the significant assumptions being related to drilling rates, fleet utilization, operating expenses, capital expenditures, residual value and the estimated remaining useful life of each rig/drillship. The assumptions used to develop estimates of future undiscounted cash flows are based on historical trends as well as future expectations. To the extent impairment indicators are present, the Company determines undiscounted projected net operating cash flows for each rig/drillship and compares them to the rig or drillship's carrying value. The projected net operating cash flows are determined by considering the drilling revenues from existing drilling contracts for the fixed days and an estimated daily rate equivalent for the unfixed days. The salvage value used in the impairment test is estimated to be $35 million and $50 million for drilling rigs and drillships respectively in accordance with the Company's depreciation policy. If the Company's estimate of undiscounted future cash flows for any drilling rig or drillship is lower than the carrying value, the carrying value is written down, by recording a charge to operations, to the vessel's fair market value if the fair market value is lower than the vessel's carrying value. The Company's analysis for the year ended December 31, 2012, which also involved sensitivity tests on the drilling rates and fleet utilization (being the most sensitive inputs to variances), allowing for variances ranging from 97.5% to 92.5%, indicated no impairment on any of its drilling rigs or drillships. Although the Company believes that the assumptions used to evaluate potential impairment are reasonable and appropriate, such assumptions are highly subjective. There can be no assurance as to how long drilling rates and drilling rigs or drillship values will remain at their currently high levels. As a result of the impairment review, the Company determined that the carrying amounts of its assets held for use were recoverable, and therefore, concluded that no impairment loss was necessary for 2010, 2011 and 2012.

(p) Class costs: The Company follows the direct expense method of accounting for periodic class costs incurred during special surveys of drilling rigs and drillships, normally every five years. Class costs and other maintenance costs are expensed in the period incurred and included in "Drilling rigs and drillships operating expenses."

(q) Deferred financing costs: Deferred financing costs include fees, commissions and legal expenses associated with the Company's long- term debt. These costs are amortized over the life of the related debt using the effective interest method and are included in interest expense. Unamortized fees relating to loans repaid or refinanced as debt extinguishments are expensed as interest and finance costs in the period the repayment or extinguishment is made. Amortization and write offs for each of the years ended December 31, 2010, 2011 and 2012, amounted to $5,078, $17,778 and $12,944, respectively (Note 14).

F-13

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

2. Significant Accounting Policies-(continued):

(r) Revenue and related expenses:

Revenues: The Company's services and deliverables are generally sold based upon contracts with customers that include fixed or determinable prices. The Company recognizes revenue when delivery occurs, as directed by its customer, or the customer assumes control of physical use of the asset and collectability is reasonably assured. The Company evaluates if there are multiple deliverables within its contracts and whether the agreement conveys the right to use the drill rigs and drillships for a stated period of time and meets the criteria for lease accounting, in addition to providing a drilling services element, which is generally compensated for by day rates. In connection with drilling contracts, the Company may also receive revenues for preparation and mobilization of equipment and personnel or for capital improvements to the drilling rigs or drillships and day rate or fixed price mobilization and demobilization fees. Revenues are recorded net of agents' commissions. There are two types of drilling contracts: well contracts and term contracts.

(i) Well contracts: Well contracts are contracts under which the assignment is to drill a certain number of wells. Revenue from day-rate based compensation for drilling operations is recognized in the period during which the services are rendered at the rates established in the contracts. All mobilization revenues, direct incremental expenses of mobilization and contributions from customers for capital improvements are initially deferred and recognized as revenues and expenses, as applicable, over the estimated duration of the drilling period. To the extent that expenses exceed revenue to be recognized, they are expensed as incurred. Demobilization revenues and expenses are recognized over the demobilization period. All revenues for well contracts are recognized as "Service revenues" in the statement of operations.

(ii) Term contracts: Term contracts are contracts under which the assignment is to operate the unit for a specified period of time. For these types of contracts the Company determines whether the arrangement is a multiple element arrangement containing both a lease element and drilling services element. For revenues derived from contracts that contain a lease, the lease elements are recognized as "Leasing revenues" in the statement of operations on a basis approximating straight line over the lease period. The drilling services element is recognized as "Service revenues" in the period in which the services are rendered at estimated fair value. Revenues related to the drilling element of mobilization and direct incremental expenses of drilling services are deferred and recognized over the estimated duration of the drilling period. To the extent that expenses exceed revenue to be recognized, they are expensed as incurred. Demobilization fees and expenses are recognized over the demobilization period. Contributions from customers for capital improvements are initially deferred and recognized as revenues over the estimated duration of the drilling contract.

(s) Earnings per common share: Basic earnings per common share are computed by dividing net income/(loss) available to common stockholders by the weighted average number of common shares outstanding during the year. Diluted earnings per common share reflect the potential dilution that could occur if securities or other contracts to issue common stock were exercised.

(t) Segment reporting: The Company has determined that it operates in one reportable segment, the offshore drilling operations.

(u) Financial instruments: The Company designates its derivatives based upon guidance on ASC 815, "Derivatives and Hedging" which establishes accounting and reporting requirements for derivative instruments, including certain derivative instruments embedded in other contracts, and for hedging activities. The guidance on accounting for certain derivative instruments and certain hedging activities requires all derivative instruments to be recorded on the balance sheet as either an asset or liability measured at its fair value, with changes in fair value recognized in earnings unless specific hedge accounting criteria are met.

(i) Hedge accounting: At the inception of a hedge relationship, the Company formally designates and documents the hedge relationship to which the Company wishes to apply hedge accounting and the risk management objective and strategy undertaken for the hedge. The documentation includes identification of the hedging instrument, hedged item or transaction, the nature of the risk being hedged and how the entity will assess the hedging instrument's effectiveness in offsetting exposure to changes in the hedged item's cash flows attributable to the hedged risk. Such hedges are expected to be highly effective in achieving offsetting changes in cash flows and are assessed on an ongoing basis to determine whether they actually have been highly effective throughout the financial reporting periods for which they were designated.

F-14

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

2. Significant Accounting Policies-(continued):

(u) Financial instruments - continued:

The Company is party to interest swap agreements where it receives a floating interest rate and pays a fixed interest rate for a certain period in exchange. Contracts which meet the strict criteria for hedge accounting are accounted for as cash flow hedges. A cash flow hedge is a hedge of the exposure to variability in cash flows that is attributable to a particular risk associated with a recognized asset or liability, or a highly probable forecasted transaction that could affect profit or loss.

The effective portion of the gain or loss on the hedging instrument is recognized directly as a component of "Accumulated other comprehensive income/(loss)" in equity, while any ineffective portion, if any, is recognized immediately in current period earnings.

The Company discontinues cash flow hedge accounting if the hedging instrument expires and it no longer meets the criteria for hedge accounting or designation is revoked by the Company. At that time, any cumulative gain or loss on the hedging instrument recognized in equity is kept in equity until the forecasted transaction occurs. When the forecasted transaction occurs, any cumulative gain or loss on the hedging instrument is recognized in the statement of operations. If a hedged transaction is no longer expected to occur, the net cumulative gain or loss recognized in equity is transferred to net profit or loss for the year as financial income or expense.

(ii) Other derivatives: Changes in the fair value of derivative instruments that have not been designated as hedging instruments are reported in current period earnings.

(v) Fair value measurements: The Company follows the provisions of ASC 820, "Fair Value Measurements and Disclosures" which defines and provides guidance as to the measurement of, fair value. ASC 820 creates a hierarchy of measurement and indicates that, when possible, fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. The fair value hierarchy gives the highest priority (Level 1) to quoted prices in active markets and the lowest priority (Level 3) to unobservable data, for example, the reporting entity's own data. Under the standard, fair value measurements are separately disclosed by level within the fair value hierarchy (Note 10).

(w) Income taxes: Income taxes have been provided for based upon the tax laws and rates in effect in the countries in which the Company's operations are conducted and income is earned. There is no expected relationship between the provision for/or benefit from income taxes and income or loss before income taxes because the countries in which the Company operates have taxation regimes that vary not only with respect to the nominal rate, but also in terms of the availability of deductions, credits and other benefits. Variations also arise because income earned and taxed in any particular country or countries may fluctuate from year to year. Deferred tax assets and liabilities are recognized for the anticipated future tax effects of temporary differences between the financial statement basis and the tax basis of the Company's assets and liabilities using the applicable jurisdictional tax rates in effect at the year end. A valuation allowance for deferred tax assets is recorded when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. The Company accrues interest and penalties related to its liabilities for unrecognized tax benefits as a component of income tax expense.

(x) Pensions: The Company has eight retirement plans, of which five are managed and funded through Norwegian life insurance companies and three through international life insurance companies. The projected benefit obligations are calculated based on the projected unit credit method and compared with the fair value of pension assets.

Because a significant portion of the pension liability will not be paid until well into the future, numerous assumptions have to be made when estimating the pension liability at the balance sheet date. The assumptions may be split into two categories; actuarial assumptions and financial assumptions. The actuarial assumptions are unbiased, mutually compatible and represent the Company's best estimates of the variables. The financial assumptions are based on market expectations at the balance sheet date, for the period over which the obligations are to be settled. Due to the long-term nature of the pension obligations, they are discounted to present value.

F-15

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

2. Significant Accounting Policies-(continued):

(x) Pension and retirement benefit obligation - continued: The funded status or net amount of the projected benefit obligation and pension asset (net pension liability or net pension asset) of each of its defined benefit plans, is recorded in the balance sheet under the caption "Pensions" with an offsetting amount in "Accumulated other comprehensive income/(loss)" for any amounts of actuary gains of losses or prior service cost that has not been amortized to income. Net pension costs (benefit earned during the period including interest on the projected benefit obligation, less estimated return on pension assets and amortization of accumulated changes in estimates) are included in "General and administrative expenses" and "Drilling rigs and drillships operating expenses". Actuarial gains and losses are recognized as income or expense when the net cumulative unrecognized actuarial gains and losses for each individual plan at the end of the previous reporting year exceed 10% of the higher of the present value of the defined benefit obligation and the fair value of plan assets at that date. These gains and losses are recognized over the expected average remaining working lives of the employees participating in the plans.

(y) Commitments and contingencies: Provisions are recognized when: the Company has a present legal or constructive obligation as a result of past events; it is probable that an outflow of resources embodying economic benefits will be required to settle the obligation; and a reliable estimate of the amount of the obligation can be made. Provisions are reviewed at each balance sheet date.

(z) Stock-based compensation: Stock-based compensation represents vested and non-vested common stock granted to certain employees for their services. The Company calculates total compensation expense for the award based on its fair value on the grant date and amortizes the total compensation on an accelerated basis over the vesting period of the award or service period (Note 12).

(aa) Recent accounting pronouncements: There are no recent accounting pronouncements issued in 2012, whose adoption would have a material impact on the Company's consolidated financial statements in the current year or are expected to have a material impact on future years.

F-16

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

3. Transactions with Related Parties:

Drillship Management Agreements with Cardiff Marine Inc. ("Cardiff"): Cardiff engages primarily in the management of ocean-going vessels, including but not limited to vessels owned by DryShips. Cardiff is beneficially majority-owned by the Chairman and Chief Executive Officer of Ocean Rig UDW and DryShips, Mr. George Economou. As the Company's Chairman and Chief Executive Officer and principal shareholder of DryShips, with a 14.4% shareholding, George Economou has the ability to exert influence over the operations of the Company. Effective December 21, 2010, the Company terminated its management agreements with Cardiff pursuant to which Cardiff provided supervisory services in connection with the construction of the drillships Ocean Rig Corcovado and Ocean Rig Olympia. The Company had paid Cardiff a management fee of $40 per month per drillship for Ocean Rig Corcovado and Ocean Rig Olympia. The management agreements also provided for: (i) a chartering commission of 1.25% on revenue earned; (ii) a commission of 1% on the shipyard payments or purchase price paid for drillships; (iii) a commission of 1% on loan financing or refinancing; and (iv) a commission of 2% on insurance premiums. These agreements were replaced by the agreement with Vivid Finance Limited, Global Services Agreement and New Global Services Agreement discussed below. During the years ended December 31, 2010 and 2011, total charges from Cardiff under the management agreements amounted to $4.0 million and $5.8 million, respectively. All incurred costs from management service agreements are directly attributable to the construction of the drillships and are capitalized as a component of "Advances for drillships under construction."

Global Services Agreement: On December 1, 2010, DryShips entered into a Global Services Agreement with Cardiff, effective December 21, 2010, pursuant to which DryShips engaged Cardiff to act as consultant on matters of chartering and sale and purchase transactions for the offshore drilling units operated by the Company. Under the Global Services Agreement, Cardiff, or its subcontractor, (i) provided consulting services related to the identification, sourcing, negotiation and arrangement of new employment for offshore assets of the Company and its subsidiaries; and (ii) identified, sourced, negotiated and arranged the sale or purchase of the offshore assets of the Company and its subsidiaries. In consideration of such services, DryShips paid Cardiff a fee of 1.0% in connection with employment arrangements and 0.75% in connection with sale and purchase activities. For the year ended December 31, 2011, the Company incurred a cost of $7,251 related to the Global Services Agreement of which $2,357 is related to employment arrangements and $4,894 to sale and purchase activities. For the year ended December 31, 2012, the Company incurred a cost of $7,153 related to Global Services Agreement of which $6,193 is related to employment arrangements and $960 is related to sale and purchase activities. The Company did not pay for services provided in accordance with this agreement since equal equity contributions were made by DryShips. Costs from the Global Services Agreement were expensed in the consolidated statement of operations or capitalized as a component of "Advances for drillships under construction" being a directly attributable cost to the construction, as applicable, and as a shareholders' contribution to capital ("Additional paid-in capital").

Effective January 1, 2013, DryShips terminated the Global Services Agreement with Cardiff. The Global Services Agreement has been replaced by the New Global Services Agreement, effective as of January 1, 2013, between Ocean Rig Management Inc. ("Ocean Rig Management"), a wholly-owned subsidiary of Ocean Rig UDW, and Cardiff Oil & Gas Management (to be renamed Cardiff Drilling Inc.) ("Cardiff Drilling"), a company controlled by the Company's Chairman, President and Chief Executive Officer, Mr. George Economou, with the same terms and conditions as in the previous Global Services Agreement between DryShips and Cardiff, except that under the New Global Services Agreement, the Company is obligated to pay directly the fees of 1.0% in consideration of employment arrangements under the agreement and $0.75% in consideration of purchase and sale activities under the agreement, whereas under the Global Services Agreement, those fees were paid by DryShips.

F-17

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

3. Transactions with Related Parties-(continued):

Vivid Finance Limited: Under the consultancy agreement effective from September 1, 2010, between DryShips and Vivid Finance Limited ("Vivid"), a company controlled by the Chairman, President and Chief Executive Officer of the Company and DryShips, Mr. George Economou, pursuant to which Vivid acts as a consultant on financing matters for DryShips and its affiliates, Vivid provided the Company with financing-related services such as (i) negotiating and arranging new loan and credit facilities, interest rate swap agreements, foreign currency contracts and forward exchange contracts, (ii) renegotiating existing loan facilities and other debt instruments and (iii) the raising of equity or debt in the capital markets. In exchange for its services in respect of the Company, Vivid was entitled to a fee equal to 0.20% on the total transaction amount. The consultancy agreement has a term of five years and may be terminated (i) at the end of its term unless extended by mutual agreement of the parties; (ii) at any time by the mutual agreement of the parties; and (iii) by DryShips after providing written notice to Vivid at least 30 days prior to the actual termination date. The Company did not pay for services provided in accordance with this agreement, DryShips paid for the services. Accordingly, these expenses were recorded in the consolidated statement of operations (or as otherwise required by US GAAP) and as a shareholders contribution to capital ("Additional paid-in capital"). During the years ended December 31, 2010, 2011 and 2012, total charges from Vivid under the agreement amounted to $1.0 million, $5.2 million and $10.8 million, respectively.

Effective January 1, 2013, Ocean Rig Management entered into a new consultancy agreement with Vivid, on the same terms and conditions as the consultancy agreement, dated as of September 1, 2010, between DryShips and Vivid, except that under the new agreement, the Company is obligated to pay directly the fee of 0.20% to Vivid on the total transaction amount in consideration of the services provided, whereas under the consultancy agreement between DryShips and Vivid, this fee was paid by DryShips.

In connection with Ocean Rig Management's entry into the new consultancy agreement described above, the consultancy agreement between DryShips and Vivid was amended, effective as of January 1, 2013, to limit the scope of the services provided under the agreement to DryShips and its subsidiaries or affiliates, except for Ocean Rig UDW and its subsidiaries.

Basset Holdings Inc.: Under the consultancy agreement effective from June 1, 2012, between Ocean Rig UDW and Basset Holdings Inc. ("Basset"), a related party entity incorporated in the Republic of Marshall Islands, Basset provides consultancy services relating to the services of Anthony Kandylidis in his capacity as Executive Vice-President of Ocean Rig UDW. The annual remuneration to be awarded to Basset under the consultancy agreement is Euro 0.9 million ($1.2 million based on the Euro/U.S. Dollar exchange rate as of December 31, 2012). For the year ended December 31, 2012, the Company incurred costs of $2.5 million, including a sign on bonus of Euro 1.5 million ($1.8 million based on the Euro/U.S. Dollar exchange rate at the date that the transaction was recorded) related to this agreement.

Private offering

A company controlled by DryShips' Chairman, President and Chief Executive Officer, Mr. George Economou, purchased 2,869,428 common shares, or 2.38% of the Company's outstanding common shares, in the private offering that was completed on December 21, 2010. The offering price was $17.50 per share. The price per share paid was the same as that paid by other investors taking part in the private offering.

In April 2012, companies affiliated with the Company`s Chairman and Chief Executive Officer, George Economou, purchased a total of 2,185,000 common shares of the Company in the public offering of the Company's common shares by DryShips that was completed on April 17, 2012.

Novation of drillship options agreement from DryShips

On November 22, 2010, DryShips entered into an option contract with Samsung for the construction of up to four ultra-deepwater drillships. The new orders were "sister-ships" to the Ocean Rig Corcovado, Ocean Rig Olympia, Ocean Rig Poseidon and Ocean Rig Mykonos and had the same specifications as the Ocean Rig Poseidon. Each of the four options to build a drillship were to be exercised on or prior to November 22, 2011, with drillships deliveries ranging from 2013 until 2014 depending on when the options were exercised (Note 8). The agreement included a non-refundable slot reservation fee of $24.8 million per drillship, which was paid by DryShips, and was applied towards the drillship contract price upon options exercise. This agreement was novated to the Company by DryShips on December 30, 2010, at a cost of $99.0 million.

F-18

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

3. Transactions with Related Parties-(continued):

Intercompany loan

During March and April 2011, the Company borrowed an aggregate of $175.5 million, without interest, from DryShips through shareholder loans for capital expenditures and general corporate purposes. On April 20, 2011, these intercompany loans were repaid.

Legal Services

Mr. Savvas D. Georghiades, a member of the Company's board of directors, provides legal services to the Company and to its predecessor, Primelead Limited through his law firm, Savvas D. Georghiades, Law Office. In the years ended December 31, 2010, 2011 and 2012, the Company and Primelead Limited expensed and paid fees amounting to, Euro 94,235 ($125 based on the Euro/U.S. Dollar exchange rate at December 31, 2010), Euro 47,390 ($61 based on the Euro/U.S. Dollar exchange rate at December 31, 2011) and Euro 41,623 ($55 based on the Euro/U.S. Dollar exchange rate at December 31, 2012), respectively for the legal services provided by Mr. Georghiades. No balance due to Mr. Savvas D. Georghiades existed as of December 31, 2011 and 2012.

4. Other Current Assets

The amount of other current assets shown in the accompanying consolidated balance sheets is analyzed as follows:

	December 31,
	2011		2012
Inventories	$	10,706	$	13,727
Deferred mobilization expenses		38,052		46,407
Prepayments and advances		11,521		14,789
Swap cash collateral		-		8,000
Other		4,969		10,716
	$	65,248	$	93,639

5. Advances for drillships under construction:

The amounts shown in the accompanying consolidated balance sheets include milestone payments under the shipbuilding contracts with the shipyards, supervision costs and any material related expenses incurred during the construction periods, all of which are capitalized in accordance with the accounting policy discussed in Note 2. For the years ended December 31, 2011 and 2012, the movement of the advances for drillships under construction and acquisitions was as follows:

	December 31,
	2011			2012
Balance at beginning of year	$	1,888,490		$	754,925
Advances for drillships under construction and related costs		2,238,591			237,900
Drillships delivered		(3,372,156	)		-
Balance at end of year	$	754,925		$	992,825

On January 3, March 30, July 28 and September 30, 2011, the Company took delivery of its newbuilding drillships, Ocean Rig Corcovado, Ocean Rig Olympia, Ocean Rig Poseidon and Ocean Rig Mykonos, respectively.

On April 18, 2011, April, 27, 2011, June 23, 2011 and September 20, 2012, pursuant to the option contract with Samsung (Note 8), Ocean Rig UDW exercised four of its six newbuilding drillship options, and entered into shipbuilding contracts for four seventh generation ultra-deepwater drillships, namely Ocean Rig Mylos, Ocean Rig Skyros, Ocean Rig Athena, and Ocean Rig Apollo for a total contractual cost of approximately $608,000, per drillship for the initial three, and $622,756 for the fourth one. To date, the Company has paid $879,387 to the shipyard in connection with the exercise of these options. Delivery of these hulls is scheduled for July 2013, October 2013, November 2013 and January 2015, respectively.

F-19

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

6. Drilling rigs, drillships, machinery and equipment, net:

The amounts in the accompanying consolidated balance sheets are analyzed as follows:

	Cost			Accumulated Depreciation			Net Book Value
Balance December 31, 2010		1,440,117			(190,784	)		1,249,333
Additions		78,480			-			78,480
Transfer from drillships under construction		3,372,156			-			3,372,156
Disposals		(1,147	)		381			(766	)
Depreciation		-			(160,365	)		(160,365	)
Balance December 31, 2011	$	4,889,606		$	(350,768	)	$	4,538,838
Additions		82,939			-			82,939
Disposals		(4,148	)		3,835			(313	)
Depreciation		-			(222,002	)		(222,002	)
Balance December 31, 2012	$	4,968,397			(568,935	)		4,399,462

As of December 31, 2011 and 2012, all of the Company's operating drilling rigs and drillships have been pledged as collateral to secure the Company's 6.50% senior secured notes due 2017 and bank loans discussed in Note 9.

7. Intangible Assets:

The Company's identified finite-lived intangible assets associated with trade names and software are being amortized over their useful lives. Trade names and software are included in "Intangible assets, net" in the accompanying consolidated balance sheets net of accumulated amortization.

							Amortization Schedule
	Balance as of December 31, 2011		Amortization for the year ended December 31, 2012		Balance as of December 31, 2012		2013		2014		2015		2016		2017 and thereafter
Trade names	$	5,512	$	877	$	4,635	$	877	$	877	$	877	$	877	$	1,127
Software		3,550		566		2,984		566		566		566		566		720
Total intangible Assets, net		9,062	$	1,443	$	7,619	$	1,443	$	1,443	$	1,443	$	1,443	$	1,847

F-20

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

8. Other non-current assets

The amount of other non-current assets shown in the accompanying consolidated balance sheets is analyzed as follows:

	December 31,
		2011		2012

Security deposits for derivatives	$	33,100	$	-
Option for construction of drillships (Note 5)		24,756		-
Deferred mobilization expenses		24,176		53,615
Other		9,049		18,150
Total	$	91,081	$	71,765

As of December 31, 2011, security deposits of $33,100 for Ocean Rig Mykonos, were recorded as "Other non-current assets" in the accompanying consolidated balance sheet. These deposits were required by the counterparties for the Company's interest rate swap agreements. These security deposits were released during the second quarter of 2012 following the commencement of operations of the Ocean Rig Mykonos.

On November 22, 2010, DryShips, entered into an option contract with Samsung for the construction of up to four ultra-deepwater drillships, which will be "sister-ships" to the Ocean Rig Corcovado, Ocean Rig Olympia, Ocean Rig Poseidon and the Ocean Rig Mykonos, with certain upgrades to vessel design and specifications. The option agreement required DryShips to pay a non-refundable slot reservation fee of $24,756 per drillship, with such fee to be applied towards the drillship contract price if the options are exercised. The option agreement was novated by DryShips to the Company on December 30, 2010. During 2011, the Company exercised three of the above options and as a result, the slot reservation fee for the three options exercised amounting to $74,268 was transferred to "Advances for drillships under construction". On May 16, 2011, the Company entered into an addendum to the option contract for the construction of up to two additional drillships with the same contract terms, conditions and specifications as the four optional drillships under the original agreement. On September 20, 2012, the Company exercised an option and as a result the remainder slot reservation amounting to $24,756 was transferred from "Other non-current assets" to "Advances for drillships under construction". As at December 31, 2012, the Company has extended the date by which it must exercise the remaining options under the contract to March 31, 2013. Drillship deliveries of the two remaining optional drillships, if exercised, are at the reasonable discretion of Samsung, with the earliest available date based on Samsung's construction schedule.

F-21

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

9. Long-term Debt:

	December 31, 2011		December 31, 2012
Term loans/Credit facilities	$	2,279,167	$	1,607,500
9.5% Senior Unsecured Notes		500,000		500,000
6.5% Senior Secured Notes		-		800,000
Less: Deferred financing costs		(43,402)		(54,090)
Total debt		2,735,765		2,853,410
Less: Current portion		(210,166)		(169,780)

Long-term portion	$	2,525,599	$	2,683,630

9.5% Senior Unsecured Notes due 2016

On April 27, 2011, the Company issued $500,000 aggregate principal amount of its 9.5% senior unsecured notes due 2016 (the "Senior Unsecured Notes") offered in a private placement, resulting in net proceeds of approximately $487,500. The Senior Unsecured Notes are unsecured obligations and rank senior in right of payment to any future subordinated indebtedness and equally in right of payment to all of its existing and future unsecured senior indebtedness.

The Senior Unsecured Notes are not guaranteed by any of the Company's subsidiaries. Upon a change of control, which occurs if 50% or more of the Company's shares are acquired by any person or group other than DryShips or its affiliates, the noteholders will have an option to require the Company to purchase all outstanding notes at a redemption price of 100% of the principal amount thereof plus accrued and unpaid interest to the date of purchase. The contractual semi-annual coupon interest rate is 9.5% per year.

6.5% Senior Secured Notes due 2017

On September 20, 2012, the Company's wholly owned subsidiary Drill Rigs Holdings Inc. ("the Issuer"), issued $800,000 aggregate principal amount of 6.50% Senior Secured Notes due 2017 (the "Drill Rigs Senior Notes") offered in a private offering, resulting in net proceeds of approximately $781,965. The Company used a portion of the net proceeds of the notes to repay the full amount outstanding under its $1,040,000 senior secured credit facility as at September 20, 2012. The Drill Rigs Senior Notes are secured obligations and rank senior in right of payment to any future subordinated indebtedness and equally in right of payment to all of its existing and future unsecured senior indebtedness.

The Drill Rigs Senior Notes are fully and unconditionally guaranteed by the Company and certain of its existing and future subsidiaries (collectively, the "Issuer Subsidiary Guarantors" and, together with the Company, the "Guarantors").

Upon a change of control, which occurs if 50% or more of the Company's shares are acquired by any person or group other than DryShips or its affiliates, the Issuer will be required to make an offer to repurchase the Drill Rigs Senior Notes at a price equal to 101% of the principal amount thereof, plus any accrued and unpaid interest thereon to the date of repurchase. On or after October 1, 2015, the Issuer may, at its option, redeem all or a portion of the Drill Rigs Senior Notes, at one time or from time to time at 103.25% (from October 1, 2012 to September 30, 2016) or 100% (October 1, 2016 and thereafter) of the principal amount thereof, plus any accrued and unpaid interest thereon to the date of redemption.

The Drill Rigs Senior Notes and the Drill Rigs Senior Notes guarantees are secured, on a first priority basis, by a security interest in the Issuer's two semi-submersible offshore drilling rigs, the Leiv Eiriksson and the Eirik Raude, and certain other assets of the Issuer and the Issuer Subsidiary Guarantors, and by a pledge of the stock of the Issuer and the Issuer Subsidiary Guarantors, subject to certain exceptions. The contractual semi-annual coupon interest rate is 6.5% on the Drill Rigs Senior Notes.

Term Bank Loans/ Credit Facilities

The bank loans are payable in U.S. Dollars in quarterly and semi-annual installments with balloon payments due at maturity between April 2016 and December 2020. Interest rates on the outstanding loans as at December 31, 2012, are based on LIBOR plus a margin, except for an amount of $458,333 from the credit facilities which is based on a fixed rate.

F-22

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

9. Long-term Debt - (continued):

On May 9, 2012, the Company, through its wholly owned subsidiary Drillships Holdings Inc., signed an amendment under its $800,000 secured term loan agreement with Nordea Finland Plc. to, among other things, terminate the guarantee by DryShips and remove the related covenants and cross-acceleration provisions relating to DryShips' indebtedness and the Company's indebtedness under its other credit facilities. As a result of the amendment, a default by DryShips under one of its loan agreements or a default by the Company under one of its other credit facilities and the acceleration of the related debt will not result in a cross-default under the Company's $800,000 secured term loan agreement that would provide the Company's lenders with the right to accelerate the outstanding debt under the loan agreement. In addition, under the terms of the loan agreement, as amended, (i) the Company is permitted to buy back its own common shares; (ii) Drillships Holdings Inc., is able to pay dividends to Ocean Rig UDW as its shareholder; and (iii) the Company is permitted to pay dividends or make any other distributions to its shareholders up to 50% of its net income, provided it maintains minimum liquidity in an aggregate amount of not less than $200,000 in cash and cash equivalents and restricted cash in the previous year from the date of the dividend, distribution or buy back of share capital and provide evidence to the lenders through cash flow forecasts that it will maintain such level for the next 12 months. The amendment also provides for a reduction in the amount of minimum free cash required to be maintained by Drillships Holdings Inc. from $75,000 to $50,000. Under the original and the amended agreements, the Company is also required to maintain minimum free cash of $100,000.

On May 14, 2012, the Company signed amendments to its two $495,000 credit facilities with Deutsche Bank Luxembourg SA. as agent (the "Deutsche Bank Credit Facilities") to, among other things, remove the payment guarantee of DryShips, subject to reinstatement as discussed below and remove the financial covenants for DryShips and the cross-default provision relating to DryShips' outstanding indebtedness. As a result of the amendments, a default by DryShips under one of its loan agreements will not result in a cross-default under the Deutsche Bank Credit Facilities that would provide the lenders thereunder with the right to accelerate the Company's outstanding debt. In addition, the amendments removed the automatic prepayment mechanism under the facilities. The Company is also required to increase its debt service reserve account by $57,000 beginning September 2014. Furthermore, under the amended Deutsche Bank Credit Facilities, the Company is permitted to pay dividends, make distributions and effect redemptions or returns of share capital up to 50% of net income, provided it maintains minimum liquidity in an aggregate amount of not less than $200,000 in cash and cash equivalents and restricted cash evidenced through cash flow forecasts for the next 12 months following the date of the dividend, distribution or redemption or return of share capital. Under the terms of the amended Deutsche Bank Credit Facilities, in the event of a breach by the Company of the financial covenants, the unconditional and irrevocable payment guarantees of DryShips will be reinstated; pursuant to which DryShips will be obligated to pay, upon demand by the lenders, any amount outstanding under the loans upon a failure by the Company to pay such amount. In addition, DryShips will be required to indemnify the lenders in respect of any losses they incur in respect of any amounts due under the loans that are not recoverable from DryShips under the guarantees and that the Company fails to pay. The amount payable by DryShips under the guarantees will be limited to $214,000 with respect to the facility for the Ocean Rig Poseidon and $225,000 with respect to the facility for the Ocean Rig Mykonos, in each case plus any other amounts that become payable in connection with the payment of such amount. The guarantees do not include any financial covenants applicable to DryShips or cross-default provisions in relation to DryShips' indebtedness for its drybulk carrier and tanker fleet.

On May 18, 2012, the Company signed an amendment under its $1,040,000 credit facility with DNB Bank ASA as agent, to amend the facility to among other things, replace the cross-acceleration clause relating to DryShips' indebtedness with cross-acceleration clause to the Company's indebtedness under its other credit facilities. In September 2012 , the outstanding balance of the loan has been fully repaid from the proceeds of the offering of Drill Rigs Senior Notes, as discussed above.

The outstanding bank loans are secured by among other things, a first priority mortgage over the Company's operating drillships and drill rigs, corporate guarantee, and a first assignment of all freights, earnings, insurances and requisition compensation. The loan agreements contain covenants, minimum liquidity requirements, maintaining working capital above certain level and restrictions, without the bank's prior consent, as to pay dividends, changes in management and ownership of the vessels, additional indebtedness and mortgaging of vessels, change in the general nature of the Company's business, and maintaining an established place of business in the United States or the United Kingdom.

Total interest and debt amortization cost incurred on long-term debt for the years ended December 31, 2010, 2011 and 2012, amounted to $35,827, $105,283 and $148,763, respectively, of which $35,780, $57,761 and $44,951 respectively, were capitalized as part of the cost of the drillships under construction. Total interest incurred and amortization of debt issuance cost on long-term debt, net of capitalized interest, are included in "Interest and finance costs" in the accompanying consolidated statement of operations.

F-23

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

9. Long-term Debt - (continued):

The Company's weighted average interest rates on the above bank loans and notes were 4.5%, 4.2% and 4.9%, as of December 31, 2010, 2011, and 2012, respectively.

Loan movements for the Company's Senior Unsecured Notes, Drill Rigs Senior Notes, credit facilities and term bank loans throughout 2012, is as follows:

Loan	Loan Agreement Date	Original Amount		December 31, 2011		New Loans		Repayments		December 31, 2012

Term Bank Loan	April 18, 2011	$	800,000	$	766,667	$	-	$	(66,667)	$	700,000
Credit Facility	September 17, 2008		1,040,000		522,500		-		(522,500)		-
Credit Facility	July 18, 2008		1,125,000		990,000		-		(82,500)		907,500
Senior Unsecured Notes	April 27, 2011		500,000		500,000		-		-		500,000
Drill Rigs Senior Notes	September 20, 2012	$	800,000		-		800,000		-		800,000


				$	2,779,167	$	800,000	$	(671,667)	$	2,907,500

The annual principal payments required to be made after December 31, 2012, including balloon payments, totaling $2,907,500 due through December 2020, are as follows:


2013	$	176,667
2014		176,667
2015		176,666
2016		1,110,000
2017		910,000
2018 and thereafter		357,500
Total principal payments		2,907,500
Less: Financing fees		(54,090	)
Total debt	$	2,853,410

F-24

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

10. Financial Instruments and Fair Value Measurements:

ASC 815, "Derivatives and Hedging" requires companies to recognize all derivative instruments as either assets or liabilities at fair value in the statement of financial position. The Company recognizes all derivative instruments as either assets or liabilities at fair value on its consolidated balance sheets.

For derivative instruments that are designated and qualify as a cash flow hedge, the effective portion of the gain or loss on the derivative is reported as a component of other comprehensive income/(loss) and reclassified into earnings in the same period or periods during which the hedged transaction affects earnings. Gains and losses on the derivative representing either hedge ineffectiveness or hedge components excluded from the assessment of effectiveness are recognized in the accompanying consolidated statement of operations. Changes in the fair value of derivative instruments that have not been designated as hedging instruments are reported in the accompanying consolidated statement of operations.

The Company enters into interest rate swap transactions to manage interest costs and risk associated with changing interest rates with respect to its variable interest rate loans and credit facilities. The Company also enters from time to time into foreign currency forward contracts in order to manage risks associated with fluctuations in foreign currencies. All of the Company's derivative transactions are entered into for risk management purposes.

10.1 Interest rate swaps and cap and floor agreements: As of December 31, 2010, the Company had outstanding eleven interest rate swap and cap and floor agreements, with a notional amount of $908 million, maturing from September 2011 through November 2017. As of December 31, 2011, the Company had outstanding seven interest rate swap and cap and floor agreements, with a notional amount of $989 million maturing from September 2013 through November 2017. As of December 31, 2012, the Company had outstanding twelve interest rate swap and cap and floor agreements, with a notional amount of $2,735 million, maturing from September 2013 through November 2017.

As of December 31, 2010, eight of these agreements did not qualify for hedge accounting and, as such, changes in their fair values are included in the accompanying consolidated statement of operations while three agreements did qualify for hedge accounting and, as such, changes in their fair values were included in other comprehensive income/(loss). Effective January 1, 2011, the Company removed the designation of the cash flow hedges and discontinued hedge accounting for the associated interest rate swaps. As a result, as of December 31, 2011 and 2012, these agreements do not qualify for hedge accounting and, as such, changes in their fair values are included in the accompanying consolidated statement of operations. In accordance with ASC 815-30-40 the accumulated unrealized loss recorded in "Accumulated Other Comprehensive Income/(Loss) " for previously designated cash flow hedges, which as of December 31, 2010, amounted to $35,992, is being reclassified into earnings in the same period or periods during which the hedged forecasted transaction affects earnings. As a result, during the year ended December 31, 2011, an amount of $9,816 was reclassified into the consolidated statement of operations. During the year ended December 31, 2012 and following the early repayment of the associated loan the balance of the hedge reserve amounting to $22,904 was reclassified into the consolidated statement of operations.

F-25

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

10.1 Interest rate swaps and cap and floor agreements – (continued):

Apart from the unrealized loss discussed above, as of December 31, 2010, "Accumulated Other Comprehensive Loss" also included realized losses on cash flow hedges associated with interest capitalized during prior years under "Advances for drillships under construction" amounting to $27,776, which according to ASC 815-30-35 is being reclassified into earnings in the same period or periods during which the hedged forecasted transaction affects earnings. As a result, during the year ended December 31, 2011, and following the delivery of four drillships discussed in Note 5, an amount of $722 was reclassified into the statement of operations while an amount of $3,272 was reclassified from other component of "Accumulated Other Comprehensive Loss " since this amount is associated with interest expense that was capitalized under "Advances for drillships under construction". During the year ended December 31, 2012, an amount of $1,034 was reclassified into the statement of operations. The estimated amount in other comprehensive income/(loss) of cash flow hedge losses at December 31, 2012, that will be reclassified into earnings within the next twelve months, is $1,034.

As of December 31, 2011 and 2012, security deposits of $33,100 and $8,000, respectively were provided as security by the Company. The Company has deposited also cash collateral of $6,000 that is classified as current restricted cash. These amounts are expected to be released upon the delivery of Ocean Rig Mylos, Ocean Rig Skyros and Ocean Rig Athena (Note 5)

10.2 Foreign currency forward contracts: As of December 31, 2010, the Company had outstanding twelve forward contracts to sell $28 million for NOK 174 million. As of December 31, 2011 and 2012, the Company had no outstanding forward contracts. The change in the fair value of such agreements for the years ended December 31, 2010 and 2011, amounted to a gain of $1,104 and a loss of $1,538 respectively, and is reflected under "Other, net" in the accompanying consolidated statement of operations.

Tabular disclosure of financial instruments is as follows:

Fair Values of Derivative Instruments in the Statements of Financial Position:

Derivatives not designated as Hedging Instruments	Balance Sheet Location	December 31, 2011 Fair value			December 31, 2012 Fair value
Interest rate swaps	Financial Instruments non-current assets					935
Interest rate swaps	Financial Instruments current liabilities		(40,727	)		(39,537	)
Interest rate swaps	Financial Instruments non-current liabilities		(52,025	)		(38,087	)
Total derivatives		$	(92,752	)	$	(76,689	)

The effect of Derivative Instruments on the Statements of Stockholders' Equity:

	Amount of Gain/(Loss) Recognized in Other Comprehensive Oncome/(loss) on Derivative (Effective Portion)
Derivatives Designated for Cash Flow Hedging Relationships	Year ended December 31, 2010		Year ended December 31, 2011		Year ended December 31, 2012
Interest rate swaps	$	(27,018)		-	$	-

Total	$	(27,018)		-	$	-

F-26

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

10. Financial Instruments and Fair Value Measurements-(continued):

No portion of the cash flow hedges shown above was ineffective during 2010.

During the years ended December 31, 2010, 2011 and 2012, the losses transferred from other comprehensive income/(loss) to the statement of operations were nil, $10,538 and $23,938, respectively.

The effect of Derivative Instruments on the Consolidated Statement of Operations:

				Amount of Gain/(Loss)
Derivatives not designated as hedging instruments	Location of Gain or (Loss) Recognized	Year ended December 31, 2010		Year ended December 31, 2011		Year ended December 31, 2012
Foreign currency forward contracts	Other, net	$	1,104		(1,538)	$	-
Interest rate swaps	Loss on interest rate swaps		(40,303)		(33,455)		(36,974)

Total		$	(39,199)		(34,993)	$	(36,974)

The carrying amounts of cash and cash equivalents, restricted cash, trade accounts receivable, and accounts payable and other current liabilities reported in the consolidated balance sheets approximate their respective fair values because of the short-term nature of these accounts. The carrying value approximates the fair market value for floating rate loans. The fair value of the interest rate swaps was determined using a discounted cash flow method based on market-based LIBOR swap yield curves, taking into account current interest rates and the creditworthiness of both the financial instrument counterparty and the Company. The Senior Unsecured Notes and the Drill Rigs Senior Notes have a fixed rate and their estimated fair values are determined through Level 2 inputs of the fair value hierarchy (quoted price in the over-the countermarket). The fair value of the outstanding balance of the Deutsche Bank credit facilities which have a fixed rate, is estimated through Level 2 inputs of the fair value hierarchy by discounting future cash flows using rates currently available for debt with similar terms, credit risk and remaining maturities. The estimated fair value of the above Senior Unsecured Notes, Drill Rigs Senior Notes and loans at December 31, 2012, is approximately $519,065, $798,000 and $511,453, respectively compared to a carrying value net of finance fees of $491,704, $781,001 and $450,433, respectively.

The guidance for fair value measurement applies to all assets and liabilities that are being measured and reported on a fair value basis. This guidance enables the reader of the financial statements to assess the inputs used to develop those measurements by establishing a hierarchy for ranking the quality and reliability of the information used to determine fair values. The statement requires that assets and liabilities carried at fair value be classified and disclosed in one of the following three categories.

Fair value measurements are classified based upon inputs used to develop the measurement under the following hierarchy:

Level 1--Quoted market prices in active markets for identical assets or liabilities.

Level 2--Observable market-based inputs or unobservable inputs that are corroborated by market data.

Level 3--Unobservable inputs that are not corroborated by market data.

F-27

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

10. Financial Instruments and Fair Value Measurements-(continued):

The following table summarizes the valuation of assets and liabilities measured at fair value on a recurring basis as of the valuation date.

	December 31, 2012		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Unobservable Inputs (Level 3)
Interest rate swaps-asset position		935				935
Interest rate swaps-liability position	$	(77,624)		-		(77,624)	$	-

Total	$	(76,689)		-		(76,689)	$	-

11. Pensions:

Pensions in the accompanying consolidated balance sheets are analyzed as follows:

		December 31, 2011				December 31, 2012
Pension benefit obligation		$	2,546			$	4,057

As of December 31, 2012, the Company had three pension benefit plans, out of a total of eight defined benefit and contribution plans, for 44 onshore employees managed and funded through Norwegian life insurance companies. The pension scheme is in compliance with the Norwegian law on required occupational pension.

The Company uses a January 1 measurement date for net periodic pension cost and a December 31 measurement date for benefit obligations and plan assets.

For defined benefit pension plans, the benefit obligation is the projected benefit obligation, the actuarial present value, as of the Company's December 31 measurement date, of all benefits attributed by the pension benefit formula to employee service rendered to that date. The amount for benefit to be paid depends on a number of future events incorporated into the pension benefit formula, including estimates of the average life of employees/survivors and average years of service rendered. It is measured based on assumptions concerning future interest rates and future employee compensation levels.

The following table presents the change in the projected benefit obligation for the years ended December 31:

	2011			2012
Benefit obligation at January 1	$	8,097		$	9,920
Service cost for benefits earned		1,445			1,440
Interest cost		329			259
Actuarial gains		539			20
Benefits paid		(87	)		(60)
Payroll tax of employer contribution		(57	)		(92)
Foreign currency exchange rate changes		(346	)		799
Benefit obligation at end of year	$	9,920		$	12,286

F-28

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

11. Pensions (continued):

The following table presents the change in the value of plan assets for the years ended December 31, 2011 and 2012 and the plans' funded status at December 31:

	2011			2012
Fair value of plan assets at January 1,	$	7,495		$	7,374
Expected return on plan assets		356			242
Actual return on plan assets		(604	)		(542)
Employer contributions		406			655
Settlement		(87	)		(60)
Foreign currency exchange rate changes		(192	)		560

Fair value of plan assets at end of year	$	7,374		$	8,229
Unfunded status at end of year	$	2,546		$	4,057

Amounts included in "Accumulated Other Comprehensive Loss " that have not yet been recognized in net periodic benefit cost are listed below:

	December 31,
	2010		2011		2012
Net actuarial loss	$	3,046	$	2,104	$	1,467
Prior service cost		-		-		-
Defined benefit plan adjustment, net of tax of $0	$	3,046	$	2,104	$	1,467

The accumulated benefit obligation for the pension plans represents the actuarial present value of benefit based on employee service and compensation as of a certain date and does not include an assumption about future compensation levels. The accumulated benefit obligation for the pension plans at December 31, 2011 and 2012, was $7,037, and $8,887, respectively.

The net periodic pension cost recognized in the consolidated statements of operations was $2,008, $1,534 and $1,641 for the years ended December 31, 2010, 2011 and 2012, respectively.

The following table presents the components of net periodic pension cost:

	Year ended December 31,
	2010			2011			2012
Expected return on plan assets	$	(395	)	$	(356	)	$	(242)
Service cost		2,021			1,445			1,440
Interest cost		334			329			259
Amortization of actuarial loss		47			116			184
Settlement		1			-			-
Net periodic pension cost	$	2,008		$	1,534		$	1,641

F-29

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

11. Pensions (continued):

The table below presents the components of changes in plan assets and benefit obligations recognized in other comprehensive income / (loss):

	Year Ended December 31,
	2010		2011			2012
Net actuarial loss/(gain)	$	1,101	$	234		$	(581)
Prior service cost (credit)		(1,020)		1,133			276
Amortization of actuarial loss		(506)		(425	)		942
Total defined benefit plan adjustments net of tax $0	$	(425)	$	942		$	637

The estimated net loss for pension benefits that will be amortized from accumulated other comprehensive income/(loss) into the periodic benefit cost for the next fiscal year is $226.

Pension obligations are actuarially determined and are affected by assumptions including expected return on plan assets. As of December 31, 2012, contributions amounting to $655 in total, have been made to the defined benefit pension plan.

The Company evaluates assumptions regarding the estimated long-term rate of return on plan assets based on historical experience and future expectations on investment returns, which are calculated by an unaffiliated investment advisor utilizing the asset allocation classes held by the plan's portfolios. Changes in these and other assumptions used in the actuarial computations could impact the Company's projected benefit obligations, pension liabilities, pension cost and other comprehensive income/(loss).

The Company bases its determination of pension cost on a market-related valuation of assets that reduces year-to-year volatility. This market-related valuation recognizes investment gains or losses over a five-year period from the year in which they occur. Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of assets and the actual return based on the market-related value of assets.

F-30

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

11. Pensions (continued):

The following are the weighted–average assumptions used to determine net periodic pension cost:

	December 31,
	2010		2011		2012
Weighted average assumptions
Expected return on plan assets		5.40%		4.10%		4.00%
Discount rate		4.00%		2.60%		2.30%
Compensation increases		4.00%		3.50%		3.50%

The Company's investments are managed by the insurance company Storebrand by using models presenting many different asset allocation scenarios to assess the most appropriate target allocation to produce long-term gains without taking on undue risk. US GAAP require disclosures for financial assets and liabilities that are re-measured at fair value at least annually. The following table set forth the pension assets at fair value as of December 31:


	2011		2012
Share and other equity investments	$	1,123	$	1,467
Bonds and other security – fixed yield		3,402		4,432
Bonds held to maturity		1,261		661
Properties and real estate		1,279		1,226
Money market		78		88
Other		231		355
Total plan net assets at fair value	$	7,374	$	8,229

The law requires a low risk profile hence the majority of the funds are invested in government bonds and high-rated corporate bonds.

Investments are stated at fair value. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Investments in securities traded on a national securities exchange are valued at the last reported sales price on the last business day of the year. If no sale was reported on that date, they are valued at the last reported bid price. Investments in securities not traded on a national securities exchange are valued using pricing models, quoted prices of securities with similar characteristics or discounted cash flows.

Alternative investments, binding investment in private equity, private bonds, hedge funds, and real estate assets do not have readily available market values. These estimated fair values may differ significantly from the values that would have been used had a ready market for these investments existed and such differences could be material. Private equity, private bonds, hedge funds and other investments not having an established market are valued at net assets values as determined by the investment managers, which management had determined approximates fair value. Investments in real estate assets funds are stated at the aggregate net asset value of the units of these funds, which management has determined approximate fair value. Real estate assets are valued at amounts based upon appraisal reports prepared by appraisals performed by the investment managers, which management has determined approximate fair value.

Purchases and sales of securities are recorded as of the trade date. Realized gains and losses on sales of securities are determined on the basis of average cost. Interest income is recognized on the accrual basis. Dividend income is recognized on the ex-dividend date.

F-31

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

11. Pensions (continued):

The major categories of plan assets as a percentage of the fair value of plan assets are as follows:

	December 31,
	2011		2012
Shares and other equity instruments	15	%	18%
Bonds	64	%	62%
Properties and real estate	17	%	15%
Other	4	%	5%
Total	100	%	100%

The US GAAP require disclosures for financial assets and liabilities that are re-measured at fair value at least annually. The US GAAP establish a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. Tiers include three levels which are explained below:

Level 1:

Financial instruments valued on the basis of quoted prices for identical assets in active markets. This category encompasses listed equities that over the previous six months have experienced a daily average turnover equivalent to approximately $ 3,462 or more. Based on this, the equities are regarded as sufficiently liquid to be encompassed by this level. Bonds, certificates or equivalent instruments issued by national governments are generally classified as level 1. In the case of derivatives, standardized equity-linked and interest rate futures will be encompassed by this level.

Level 2:

Financial instruments valued on the basis of observable market information not covered by level 1. This category encompasses financial instruments that are valued on the basis of market information that can be directly observable or indirectly observable. Market information that is indirectly observable means that prices can be derived from observable, related markets. Level 2 encompasses equities or equivalent equity instruments for which market prices are available, but where the turnover volume is too limited to meet the criteria in level 1. Equities on this level will normally have been traded during the last month. Bonds and equivalent instruments are generally classified as level 2. Interest rate and currency swaps, non-standardized interest rate and currency derivatives, and credit default swaps are also classified as level 2. Funds are generally classified as level 2, and encompass equity, interest rate and hedge funds.

Level 3:

Financial instruments valued on the basis of information that is not observable pursuant to level 2. Equities classified as level 3 encompass investments in primarily unlisted/private companies. These include investments in forestry, real estate and infrastructure. Private equity is generally classified as level 3 through direct investments or investments in funds. Asset backed securities (ABS), residential mortgage backed securities (RMBS) and commercial mortgage backed securities (CMBS) are classified as level 3 due to their generally limited liquidity and transparency in the market.

F-32

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

11. Pensions–(continued):

The following table sets forth by level, within the fair value hierarchy, the pension asset at fair value as of December 31, 2011:

	Level 1		Level 2		Level 3		Total
Equity securities:
US Equities	$	658		-		-	$	658
Non-US Equities		157		-		308		465
Fixed Income:
Government Bonds		2,891		549		-		3,440
Corporate Bonds		978		245		-		1,223
Alternative Investments:
Hedge funds and limited partnerships		-		231		-		231
Cash and cash equivalents		78		-		-		78
Real Estate		-		-		1,279		1,279
Net Plan Net Assets	$	4,762		1,025		1,587	$	7,374

The following table sets forth by level, within the fair value hierarchy, the pension asset at fair value as of December 31, 2012:

	Level 1			Level 2		Level 3			Total
Equity securities:
US Equities	$	887			-		-			887
Non-US Equities		209			-		371			580
Fixed Income:
Government Bonds		628			33			-		661
Corporate Bonds		3,546			886			-		4,432
Alternative Investments:
Hedge funds and limited partnerships			-		355			-		355
Cash and cash equivalents		88			-			-		88
Real Estate		-			-		1,226			1,226
Net Plan Net Assets	$	5,358			1,274		1,597			8,229

The tables below set forth a summary of changes in the fair value of the pension assets classified as level 3 investment assets for the years ended December 31, 2011 and 2012.

	Year ended December 31,
	2011		2012
Balance, beginning of year	$	1,338	$	1,587
Actual return on plan assets:
Assets still held at reporting date		177		63
Purchases, sales, issuances and settlements (net)		72		(53	)
Net Plan Net Assets	$	1,587	$	1,597

F-33

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

11. Pensions–(continued):

The following pension benefits contributions are expected to be paid by the Company during the years ending:

December 31, 2013	$	93
December 31, 2014		135
December 31, 2015		135
December 31, 2016		220
December 31, 2017		181
December 31, 2018 – 2021		2,190

Total pension payments	$	2,954

The Company's estimated employer contribution to the define benefit pension plan for the fiscal year 2013 is $1,122.

The Company has five defined contribution pension plans that include 714 employees. The contribution to the defined contribution pension plans for the years 2010, 2011 and 2012, was $1,775, $3,738 and $5,205, respectively.

12. Common Stock and Additional Paid-in Capital:

General

Prior to December 8, 2010, the Company's authorized capital stock consisted of 500 common shares, par value $20.00 per share. During December 2010, the Company adopted, amended and restated articles of incorporation pursuant to which its authorized capital stock consisted of 250,000,000 common shares, par value $0.01 per share; and (ii) declared and paid a stock dividend of 103,125,000 shares of its common stock to its sole shareholder, DryShips. On December 21, 2010, the Company completed through a private placement the sale of an aggregated of 28,571,428 common shares at $17.50 per share. The proceeds from the private placement net of directly attributable costs of $11,699 were $488,301. The stock dividend has been accounted for as a stock split. As a result, the Company reclassified approximately $1,021 from "Additional paid-in capital" to common stock, which represents the par value per share of the shares issued. All previously reported share and per share amounts have been restated to reflect the stock dividend.

On April 15, 2011, at the Company's Special Meeting of Shareholders, the Company's shareholders approved an increase in the Company's authorized share capital to 1,000,000,000 common shares, and 500,000,000 preferred shares.

On December 6, 2011, the Company announced that its board of directors had approved a repurchase program for up to a total of $500,000 of the Company's common shares and 9.5% senior unsecured notes due 2016 (Note 9). Company's common shares and unsecured notes may be purchased under the program from time to time through December 31, 2013. As of December 31, 2012, the Company had not purchased any common shares or unsecured notes under the program described above.

Restricted stock awards

On February 14, 2012, the Company's Compensation Committee approved the grant of 112,950 shares of non-vested common stock to officers and key employees of the Company's subsidiary, Ocean Rig AS, as a bonus for their services rendered during 2011. The shares vest over a period of three years. The stock-based compensation is being recognized to expenses over the vesting period and based on the fair value of the shares on the grant date of $16.50 per share.

On March 21, 2012, the Company's Board of Directors approved the 2012 Equity Incentive Plan (the "Plan") and reserved a total of 2,000,000 common shares. Under the Plan, officers, key employees, and directors are eligible to receive awards of stock options, stock appreciation rights, restricted stock, restricted stock units, phantom stock units and unrestricted stock.

On May 15, 2012, Ocean Rig's Compensation Committee approved the grant of: a) 4,500 shares of non-vested common stock to an officer as an additional bonus for his services rendered during 2011 and b) 28,200 shares to new recruited employees as a sign-up stock bonus. The shares vest over a period of three years. The stock-based compensation is being recognized to expenses over the vesting period and based on the fair value of the Ocean Rig shares on the grant date of $15.92 per share.

On December 5, 2012, 7,500 shares awarded to an officer of the Company. The fair value of the shares on the grant date was $15.75 and the shares will vest in March 2013.

F-34

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

12. Common Stock and Additional Paid-in Capital-(continued):

As of December 31, 2012, 2,500 shares have vested, while 77,150 shares were forfeited due to employees' resignations.

The movement during the year ended December 31, 2012, is presented below:

	Number of non vested shares			Weighted average grant date fair value per non vested shares

Balance December 31, 2011		-			-
Granted		153,150			16.34
Forfeited		(77,150	)		16.28
Vested		(2,500	)		16.50
Balance December 31, 2012		73,500			16.40

As of December 31, 2012, there was $633 of total unrecognized compensation cost related to non-vested share-based compensation arrangements granted by the Company. That cost is expected to be recognized over a period of three years. The amount of $613 represents the stock based compensation expense for the year and is recorded in "General and administrative expenses", in the accompanying consolidated statements of operations for the year ended December 31, 2012.

13. Accumulated other Comprehensive Loss:

The amounts in the accompanying balance sheets are analyzed as follows:

	December 31,
	2011			2012
Cash flows hedges unrealized loss	$	(22,904	)	$	-
Cash flows hedges realized loss		(30,326	)		(29,292)
Actuarial pension gain	$	2,104			1,467
Total		(51,126	)	$	(27,825)

14. Interest and Finance Cost:

The amounts in the accompanying consolidated statements of operations are analyzed as follows:

	Year ended December 31,
	2010			2011			2012
Interest costs on long-term debt	$	30,749		$	87,505		$	135,819
Amortization of financing fee		5,078			17,778			12,944
Amortization of unrealized hedge reserve (Note 10.1)		-			9,816			9,816
Capitalized borrowing costs		(35,780	)		(57,761	)		(44,951)
Bank charges		1,997			2,006			604
Commissions and commitment fees		6,374			4,408			2,195
Total	$	8,418		$	63,752		$	116,427

F-35

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

15. Income Taxes:

Ocean Rig UDW operates through its various subsidiaries in a number of countries throughout the world. Income taxes have been provided based upon the tax laws and rates in the countries in which operations are conducted and income is earned. The countries in which the Company operates have taxation regimes with varying nominal rates, deductions, credits and other tax attributes. Consequently, there is not an expected relationship between the provision for/or benefit from income taxes and income or loss before income taxes.

The components of the Company's income/(losses) before taxes are as follows:

	Year ended December 31,
	2010		2011			2012
Domestic income/(loss) (Marshall Islands)	$	174,794	$	190,940		$	(67,582)
Foreign income/(loss)		(19,597)		(68,214	)		(20,797)
Total income/(loss) before taxes	$	155,197	$	122,726		$	(88,379)

The components of the Company's tax expense were as follows:

	Year Ended December 31,
	2010		2011		2012
Current Tax expense	$	20,227	$	27,637	$	43,957
Deferred Tax expense / (benefit)		209		(209)		-
Income taxes	$	20,436	$	27,428	$	43,957

Effective tax rate		13%		22%		(50)	%

The current tax expense is mainly related to withholding tax based on total contract revenue or bareboat fees. In 2012, 97% of the current tax expense was related to withholding tax in Brazil, Angola, Equatorial Guinea, Ivory Coast and Ghana. In 2011, approximately 95% of the current tax expense was related to withholding tax in Ghana, Tanzania and Turkey, while in 2010 approximately 95% of the current tax expense was related to withholding tax in Ghana and Turkey.

Taxes have not been reflected in other comprehensive income/loss since the valuation allowances would result in no recognition of deferred tax.

	Year Ended December 31,
Reconciliation of total tax expense:	2010			2011			2012
Change in valuation allowance	$	(14,922	)	$	(41,870	)	$	6,311
Differences in tax rates		14,177			(3,288	)		(3,896	)
Effect of permanent differences		40			2			120
Adjustments in respect to current income tax of previous years		281			(766	)		184
Effect of exchange rate differences		1,465			(3,318	)		(1,599	)
Withholding tax		19,395			26,132			42,837
Loss of tax loss carry forward because of liquidation		-			50,536			-
Total	$	20,436		$	27,428		$	43,957

F-36

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

15. Income Taxes-(continued):

Ocean Rig UDW has for 2011 elected to use the statutory tax rate for each year based upon the location where the largest parts of its operations were domiciled. During 2010, 2011 and 2012, most of its activities were in Marshall Islands with tax rate of zero.

Ocean Rig UDW is subject to changes in tax laws, treaties, regulations and interpretations in and between the countries in which its subsidiaries operate. A material change in these tax laws, treaties, regulations and interpretations could result in a higher or lower effective tax rate on worldwide earnings.

Deferred tax assets and liabilities are recognized for the anticipated future tax effects of temporary differences between the financial statement basis and the tax basis of the Company's assets and liabilities at the applicable tax rates in effect. The significant components of deferred tax assets and liabilities are as follow:

	Year ended December 31,
	2011			2012
Deferred tax assets
Net operations loss carry forward	$	8,015		$	8,707
Accelerated depreciation of assets		31			107
Pension		713			1,136
Total deferred tax assets	$	8,759		$	9,950

Less: valuation allowance		(8,759	)		(9,950	)
Total deferred tax assets, net	$	-		$	-

A valuation allowance for deferred tax assets is recorded when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. The Company provides a valuation allowance to offset deferred tax assets for net operating losses ("NOL") incurred during the year in certain jurisdictions and for other deferred tax assets where, in the Company's opinion, it is more likely than not that the financial statement benefit of these losses will not be realized. The Company provides a valuation allowance for foreign tax loss carry forward to reflect the possible expiration of these benefits prior to their utilization. As of December 31, 2012, the valuation allowance for deferred tax assets is increased from $8,759 in 2011 to $9,950 in 2012 reflecting an increase in net deferred tax assets during the period. The increase is primarily a result of an increase of deferred tax assets in the Falkland Islands. This increase was partly set off by a reduction of deferred tax asset due to utilization or loss of tax loss carry forwards in Norway in 2012.

As of December 31, 2011, the net operating losses on a gross basis are $25,593 and are mainly related to losses in Norway, Brazil, Canada and Greenland. As of December 31, 2012, the net operating losses on a gross basis are $32,961 and are mainly related to Canada and the Falkland Islands. These losses are available indefinitely for offset against future taxable profits of the company in which the losses arose.

The Company's income tax returns are subject to review and examination in the various jurisdictions in which the Company operates. As of December 31, 2012 the Company was not subject to any examination on tax matters. The Company may contest any tax assessment that deviates from its tax filing. However, this review is not expected to incur any tax payables and uncertain tax positions are regarded as immaterial.

The Company's tax returns in the major jurisdictions in which it operates are generally subject to examination for periods ranging from three to six years.

The Company accrues interest and penalties related to its liabilities for unrecognized tax benefits as a component of income tax expense. During the year ended December 31, 2010, 2011 and 2012, the Company had no unrecognized tax benefits and did not incur any interest or penalties.

Ocean Rig UDW, and/or one of its subsidiaries, filed federal and local tax returns in several jurisdictions throughout the world. The amount of current tax benefit recognized during the years ended December 31, 2011 and 2012, from the settlement of disputes with tax authorities and the expiration of statute of limitations was insignificant. All earnings in foreign jurisdictions are permanently reinvested as the earnings are needed for working capital needs. Hence, no deferred tax liability has been recognized.

F-37

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

16. Geographic information for offshore drilling operations

The revenue shown in the table below is based upon the location where the drilling takes place:


Country	2010		2011		2012
Ghana/Ivory Coast	$	227,649	$	230,018	$	175,595
Turkey		176,228		50,183		-
Norway		(715)		-		-
Brazil		-		(617)		233,569
Greenland		-		253,125		136
Ivory Coast		-		89,686		-
Tanzania		-		78,424		196,415
Angola		-		-		79,884
Namibia		-		-		33,212
Falkland		-		-		166,795
Equatorial Guinea		-		-		56,297
Total leasing and service revenues	$	403,162	$	700,819	$	941,903

The drilling units Leiv Eiriksson, Eirik Raude, Ocean Rig Corcovado, Ocean Rig Olympia, Ocean Rig Poseidon and Ocean Rig Mykonos constitute the Company's long lived assets.

17. Commitments and Contingencies

17.1 Legal proceedings

Various claims, suits, and complaints, including those involving government regulations and product liability, arise in the ordinary course of the offshore drilling business.

The Company has obtained insurance for the assessed market value of the rigs and the drillships. However, such insurance coverage may not provide sufficient funds to protect the Company from all liabilities that could result from its operations in all situations. Risks against which the Company may not be fully insured or insurable for include environmental liabilities, which may result from a blow-out or similar accident, or liabilities resulting from reservoir damage alleged to have been caused by the negligence of the Company.

The Company's loss of hire insurance coverage does not protect against loss of income from day one. It covers approximately one year for the loss of time but will be effective after 45 days` off-hire. During 2012, the Ocean Rig Corcovado incurred off-hire which was a covered event under the Company's loss of hire insurance policy that resulted in $24.6 million being recognized as revenue during the year ended December 31, 2012.

The occurrence of casualty or loss, against which the Company is not fully insured, could have a material adverse effect on the Company's results of operations and financial condition.

As part of the Company's normal course of operations, the Company's customer may disagree on amounts due to the Company under the provision of the contracts which are normally settled through negotiations with the customer. Disputed amounts are normally reflected in revenues at such time as the Company reaches agreement with the customer on the amounts due.

The Leiv Eiriksson operated in Angola during the period from 2002 to 2007. Ocean Rig UDW's manager in Angola during this period made a legal claim for reimbursement of import/export duties for two export/importation events in the period 2002 to 2007 retroactively levied by the Angolan government. Agreement was reached between the parties to settle this claim for an amount of $6.1 million which was paid by the Company's relevant subsidiary on May 24, 2012, to the claimant, in full and final settlement of the London Court Proceedings. The Company recorded a charge of $6.1 million during the year ended December 31, 2012, which is included under "Legal settlements and other, net" in the consolidated statement of operations.

Except for the matters discussed above, the Company is not a party to any material litigation where claims or counterclaims have been filed against the Company other than routine legal proceedings incidental to its business.

F-38

OCEAN RIG UDW INC.

Notes to Consolidated Financial Statements

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of United States Dollars – except for share and per share data, unless otherwise stated)

17. Commitments and Contingencies–(continued):

17.2 Contractual Revenue:

Future minimum contractual revenue, based on drilling units committed to non-cancelable, contracts as of December 31, 2012, amounted to $1,131,701 for twelve months ending December 31, 2013, $1,453,513 for twelve months ending December 31, 2014, $1,141,448 for the twelve months ending December 31, 2015, $502,528 for twelve months ending December 31, 2016 and $20,371 for twelve months ending December 31, 2017. These amounts do not include any assumed off-hire.

17.3 Purchase Obligations:

The following table sets forth the Company's contractual purchase obligations as of December 31, 2012.

	2013		2014		2015		Total
Drillships shipbuilding contracts		1,179,776		-		387,100		1,566,876
Total obligations		1,179,776		-		387,100		1,566,876

17.4 Rental Payments

The Company has operating leases mostly relating to premises, the most significant being its offices in Stavanger, Rio de Janeiro, Jersey and Aberdeen. As of December 31, 2012, the future obligations amount to $2,774 for the twelve months ending December 31, 2013 and $1,396 for twelve months ending December 31, 2014 and $422 for the years ending December 31, 2015 and 2016.

18. Subsequent Events:

18.1 On January 9, 2013, the Company entered into a drilling contract with Exxonmobil Exploration and Production Ireland (Offshore) Limited, or ExxonMobil, for a one-well program for the Eirik Raude for drilling offshore Ireland. The contract has an estimated duration of up to six months The Eirik Raude is scheduled to commence this contract in the first quarter of 2013, following the completion of its current contract and the cancellation from European Hydrocarbons Limited, or European Hydrocarbons, discussed below. Under the contract, the Company has the option to extend the contract for three more wells.

18.2 On February 1, 2013, the Company entered into a firm four-well program plus options, with Lukoil Overseas Sierra-Leone B.V., or Lukoil, for the Eirik Raude for drilling offshore West Africa. The contract has estimated duration of approximately 12 months. The Eirik Raude is scheduled to commence this contract in the second half of 2013, following the completion of its contract with ExxonMobil discussed above.

18.3 On February 28, 2013, the Company signed definite documentation for a $1.35 billion syndicated secured term loan facility to partially finance the construction costs of the Ocean Rig Mylos, the Ocean Rig Skyros and the Ocean Rig Athena, three of the Companys' seventh generation drillships scheduled for delivery in July 2013, October 2013 and November 2013, respectively. The facility will have a five-year term and a repayment profile of approximately 11 years and will bear interest at LIBOR plus a margin.

18.4 On March 3, 2013, the Company's customer European Hydrocarbons Limited, or European Hydrocarbons, unilaterally cancelled the Company's drilling contract in West Africa for the Eirik Raude. Under the terms of the contract, European Hydrocarbons will have to reimburse the Company with an early termination payment of approximately $13.7 million plus accrued work performed to date. The total effect on the future revenues (Note 17) will amount to $14.1 million less revenues from this contract during fiscal year 2013.

F-39

Schedule I- Condensed Financial Information of Ocean Rig UDW Inc. (Parent Company Only)

Balance Sheets

December 31, 2011 and 2012

(Expressed in thousands of U.S. Dollars – except for share and per share data)

	2011			2012

ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	1,303		$	954
Other current assets		17,021			434
Total current assets		18,324			1,388

NON-CURRENT ASSETS:
Drillships options		24,756			-
Investments in subsidiaries*		3,469,901			3,424,157
Total non-current assets		3,494,657			3,424,157

Total assets	$	3,512,981		$	3,425,545

LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES:
Other current liabilities	$	24,826		$	14,488
Financial instruments		-			10,839
Total current liabilities		24,826			25,327

NON-CURRENT LIABILITIES
Long term debt, net of current portion		489,699			491,703
Total non-current liabilities		489,699			491,703

STOCKHOLDERS' EQUITY:
Preferred stock, $0.01 par value; 500,000,000 shares authorized at December 31, 2011 and 2012, nil issued and outstanding at December 31, 2011 and 2012, respectively		-			-
Common stock, $0,01 par value; 1,000,000,000 shares authorized, at December 31, 2011 and 2012, 131,696,928 and 131,725,128 issued and outstanding at December 31, 2011 and 2012 respectively		1,317			1,317
Additional paid-in capital		3,469,924			3,489,018
Accumulated other comprehensive loss		(51,126	)		(27,825	)
Accumulated deficit		(421,659	)		(553,995	)
Total stockholders' equity		2,998,456			2,908,515
Total liabilities and stockholders' equity	$	3,512,981		$	3,425,545

* Eliminated in consolidation

Schedule I- Condensed Financial Information of Ocean Rig UDW Inc. (Parent Company Only)

Statements of Operations

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of U.S. Dollars – except for share and per share data)

		2010		2011			2012
EXPENSES:

General and administrative expenses	$	2,456	$	8,591		$	12,877
Legal settlements and other, net		-		-			6,100
Operating loss		2,456		8,591			18,977

OTHER INCOME / (EXPENSES):
Interest and finance costs		(326)		(35,328	)		(58,210	)
Interest income		4,202		3,216			4
Loss on interest rate swaps		-		-			(38)
Other, net		37		1,068			(2,476)

Total other (expenses), net		3,913		(31,044)			(60,720	)

Equity in earnings/(loss) of subsidiaries*		133,304		134,933			(52,639)

Net income/(loss)	$	134,761	$	95,298		$	(132,336)

Earnings/(loss) per common share, basic and diluted		1.30		0.72			(1.00)

Weighted average number of shares, basic and diluted		103,908,279		131,696,928			131,696,935

* Eliminated in consolidation

Schedule I- Condensed Financial Information of Ocean Rig UDW Inc. (Parent Company Only)

Statements of Comprehensive Income/(loss)

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of U.S. Dollars – except for share and per share data)

	2010		2011		2012
Net income / (Loss)	$	134,761	$	95,298	$	(132,336)

Other Comprehensive income / (loss):
Unrealized interest rate swap gains/(losses)		(5,495)		3,272			-
Realized loss on cash flow hedges associated with capitalized interest		(21,523)		(3,272)			-
Reclassification of realized losses associated with capitalized interest to Consolidated Statement of Operations		-		722		1,034
Reclassification of losses on previously designated cash flow hedges to Consolidated Statement of Operations, net		-		9,816		22,904
Actuarial gains/(losses)		424		(942)		(637)
Other Comprehensive income/ (loss)		(26,594)		9,596		23,301
Total Comprehensive income / (loss)	$	108,167	$	104,894	$	(109,035)

Schedule I- Condensed Financial Information of Ocean Rig UDW Inc. (Parent Company Only)

Statements of Cash Flows

For the years ended December 31, 2010, 2011 and 2012

(Expressed in thousands of U.S. Dollars)


	2010			2011			2012
Net Cash Used in Operating Activities	$	(753	)	$	(28,728	)	$	(59,992	)

Cash Flows from Investing Activities:
Investments in subsidiaries		(583,498	)		(846,731	)		59,643
Drillships options		(99,024	)		-			-
Restricted cash		(302,011	)		302,011			-
Net Cash (Used in)/Provided by Investing Activities		(984,533	)		(544,720	)		59,643

Cash Flows from Financing Activities:
Due to subsidiaries		(335,223	)		334,996			-
Capital contribution from DryShips		583,498			-			-
Net proceeds from common stock issuance		488,301			-			-
Proceeds from credit facility		300,000			500,000			-
Payments of credit facility		-			(300,000	)		-
Payment of financing fees		-			(11,535	)		-
Net Cash Provided by Financing Activities		1,036,576			523,461			-
Net (decrease) / increase in cash and cash equivalents		51,290			(49,987	)		(349	)
Cash and cash equivalents at beginning of year		-			51,290			1,303
Cash and cash equivalents at end of year	$	51,290		$	1,303		$	954

Schedule I- Condensed Financial Information of Ocean Rig UDW Inc. (Parent Company Only)

In the condensed financial information of the Parent Company, the Parent Company's investment in subsidiaries is stated at cost plus equity in undistributed earnings of subsidiaries.

There are no legal or regulatory restrictions on the Parent Company's ability to obtain funds from its subsidiaries through dividends, loans or advances sufficient to satisfy the obligations discussed below that are due on or before December 31, 2013.

On December 28, 2010 the Parent Company concluded a $300,000 loan facility to be repaid during 2011. The loan was fully drawn on December 28, 2010 and fully repaid on January 3, 2011.

On April 27, 2011, the Parent Company issued $500,000 aggregate principal amount of 9.5% Senior Unsecured Notes due 2016. The notes are unsecured obligations and rank senior in right of payment to any future subordinated indebtedness and equally in right of payment to all of its existing and future unsecured senior indebtedness.

The Parent Company is guarantor on the two $495,000 facilities, the $800,000 facility and the 6.5% Senior Secured Notes due 2017 described on Note 9 "Long-term Debt" to the consolidated financial statements. As of December 31, 2012 the amount outstanding related to these three facilities amounted to $1,607,500 in aggregate and the amount outstanding related to the 6.5% Senior Secured Notes amounted to $800,000.

The condensed financial information of the Parent Company should be read in conjunction with the Company's consolidated financial statements.