Edgar Filing: HORNBECK OFFSHORE SERVICES INC /LA

Form 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2011

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

For the transition period from to

Commission file number 001-32108

Hornbeck Offshore Services, Inc.

(Exact Name of Registrant as Specified in Its Charter)


Delaware		72-1375844
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

103 NORTHPARK BOULEVARD, SUITE 300

COVINGTON, LA 70433

(Address of Principal Executive Offices) (Zip Code)

(985) 727-2000

(Registrant’s Telephone Number, Including Area Code)

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.



Large accelerated filer ¨		Non-accelerated filer ¨

Accelerated filer x		Smaller reporting company ¨

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

The total number of shares of common stock, par value $.01 per share, outstanding as of July 31, 2011 was 26,912,733.

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

FORM 10-Q FOR THE QUARTER ENDED JUNE 30, 2011

TABLE OF CONTENTS


PART I—FINANCIAL INFORMATION			1
Item 1—Financial Statements			1
Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations			11
Item 3—Quantitative and Qualitative Disclosures About Market Risk			29
Item 4—Controls and Procedures			29

PART II—OTHER INFORMATION			30
Item 1—Legal Proceedings			30
Item 1A—Risk Factors			30
Item 2—Unregistered Sales of Equity Securities and Use of Proceeds			30
Item 3—Defaults Upon Senior Securities			30
Item 4—Removed and Reserved			30
Item 5—Other Information			30
Item 6—Exhibits			30

SIGNATURE			33

PART I—FINANCIAL INFORMATION

Item 1—Financial Statements

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(IN THOUSANDS, EXCEPT PER SHARE DATA)


	June 30, 2011		December 31, 2010
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	136,538	$	126,966
Accounts receivable, net of allowance for doubtful accounts of $2,002 and $734, respectively		68,547		71,777
Other current assets		20,658		17,598

Total current assets		225,743		216,341

Property, plant and equipment, net		1,593,090		1,606,121
Deferred charges, net		46,167		41,058
Other assets		14,487		14,905

Total assets	$	1,879,487	$	1,878,425

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	38,273	$	25,100
Accrued interest		9,021		9,024
Accrued payroll and benefits		9,615		13,413
Deferred revenue		3,310		2,197
Other accrued liabilities		9,577		4,451

Total current liabilities		69,796		54,185
Long-term debt, net of original issue discount of $35,671 and $41,767, respectively		764,329		758,233
Deferred tax liabilities, net		215,689		222,413
Other liabilities		1,186		1,717

Total liabilities		1,051,000		1,036,548

Stockholders’ equity:
Preferred stock: $0.01 par value; 5,000 shares authorized; no shares issued and outstanding		—		—
Common stock: $0.01 par value; 100,000 shares authorized; 26,911 and 26,584 shares issued and outstanding, respectively		269		266
Additional paid-in-capital		418,345		415,673
Retained earnings		409,573		425,634
Accumulated other comprehensive income		300		304

Total stockholders’ equity		828,487		841,877

Total liabilities and stockholders’ equity	$	1,879,487	$	1,878,425

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

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(IN THOUSANDS, EXCEPT PER SHARE DATA)


	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
	(Unaudited)						(Unaudited)
Revenues	$	80,817		$	111,885		$	153,084		$	198,131
Costs and expenses:
Operating expenses		48,414			48,507			90,036			92,839
Depreciation		15,320			14,731			30,529			28,263
Amortization		4,773			4,585			10,165			8,896
General and administrative expenses		8,497			9,640			18,361			18,561

		77,004			77,463			149,091			148,559

Gain on sale of assets		—			95			559			619

Operating income		3,813			34,517			4,552			50,191
Other income (expense):
Interest income		240			155			419			249
Interest expense		(14,998	)		(14,274	)		(29,914	)		(25,931	)
Other income (expense), net		81			257			77			235

		(14,677	)		(13,862	)		(29,418	)		(25,447	)

Income (loss) before income taxes		(10,864	)		20,655			(24,866	)		24,744
Income tax expense (benefit)		(3,839	)		7,612			(8,805	)		9,146

Net income (loss)	$	(7,025	)	$	13,043		$	(16,061	)	$	15,598

Basic earnings (loss) per common share	$	(0.26	)	$	0.49		$	(0.60	)	$	0.59

Diluted earnings (loss) per common share	$	(0.26	)	$	0.48		$	(0.60	)	$	0.57

Weighted average basic shares outstanding		26,875			26,388			26,799			26,324

Weighted average diluted shares outstanding		26,875			27,156			26,799			27,138

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

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(IN THOUSANDS)


	Six Months Ended June 30,
	2011			2010
	(Unaudited)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	(16,061	)	$	15,598
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation		30,529			28,263
Amortization		10,165			8,896
Stock-based compensation expense		3,926			4,612
Provision for bad debts		1,268			(157	)
Deferred tax expense (benefit)		(9,551	)		8,714
Amortization of deferred financing costs		8,015			7,490
Gain on sale of assets		(559	)		(619	)
Equity in loss from investment		—			6
Changes in operating assets and liabilities:
Accounts receivable		3,096			(17,111	)
Other receivables and current assets		(3,396	)		5,499
Deferred drydocking charges		(10,380	)		(12,108	)
Accounts payable		3,489			8,291
Accrued liabilities and other liabilities		(780	)		(4,720	)
Accrued interest		(4	)		(766	)

Net cash provided by operating activities		19,757			51,888

CASH FLOWS FROM INVESTING ACTIVITIES:
Costs incurred for MPSV program		—			(8,533	)
Costs incurred for OSV newbuild program #4		—			(22,670	)
Net proceeds from sale of assets		2,055			1,458
Vessel capital expenditures		(12,194	)		(20,769	)
Non-vessel capital expenditures		(698	)		(1,344	)

Net cash used in investing activities		(10,837	)		(51,858	)

CASH FLOWS FROM FINANCING ACTIVITIES:
Deferred financing costs		(490	)		(60	)
Net cash proceeds from other shares issued		1,138			730

Net cash provided by (used in) financing activities		648			670

Effects of exchange rate changes on cash		4			81

Net increase in cash and cash equivalents		9,572			781
Cash and cash equivalents at beginning of period		126,966			51,019

Cash and cash equivalents at end of period	$	136,538		$	51,800

SUPPLEMENTAL DISCLOSURES OF CASH FLOW ACTIVITIES:
Cash paid for interest	$	21,848		$	22,316

Cash paid for income taxes	$	499		$	2,354

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

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

1. Basis of Presentation

The accompanying unaudited consolidated financial statements do not include certain information and footnote disclosures required by United States generally accepted accounting principles, or GAAP. The interim financial statements and notes are presented as permitted by instructions to the Quarterly Report on Form 10-Q and Article 10 of Regulation S-X. In the opinion of management, all adjustments necessary for a fair presentation of the interim financial statements have been included and consist only of normal recurring items. The unaudited quarterly financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Annual Report on Form 10-K of Hornbeck Offshore Services, Inc. (together with its subsidiaries, the “Company”) for the year ended December 31, 2010. The results of operations for the three and six months ended June 30, 2011 are not necessarily indicative of the results that may be expected for the year ending December 31, 2011.

The consolidated balance sheet at December 31, 2010 has been derived from the audited consolidated financial statements at that date but does not include all of the information and footnotes required by GAAP for complete financial statements.

Recent Accounting Pronouncements

In June 2011, the Financial Accounting Standards Board, or FASB, amended the presentation of comprehensive income. The amendments give the Company the option to present the total comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. These amendments are effective for fiscal years and interim periods within those years, beginning on or after December 15, 2011. The Company has not determined which method of presentation it will elect.

Other accounting standards that have been issued or proposed by the FASB or other standards-setting bodies are not expected to have a material impact on the Company’s financial position, results of operations and cash flows.

2. Earnings Per Share

Basic earnings (loss) per common share was calculated by dividing net income (loss) by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per common share was calculated by dividing net income (loss) by the weighted average number of common shares outstanding during the year plus the effect of dilutive stock options and restricted stock unit awards. Weighted average number of common shares outstanding was calculated by using the sum of the shares determined on a daily

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

basis divided by the number of days in the period. The table below reconciles the Company’s earnings (loss) per share (in thousands, except for per share data):


	Three Months Ended June 30,					Six Months Ended June 30,
	2011			2010		2011			2010
Net income (loss)	$	(7,025	)	$	13,043	$	(16,061	)	$	15,598

Weighted average number of shares of common stock outstanding		26,875			26,388		26,799			26,324
Add: Net effect of dilutive stock options and unvested restricted stock (1)(2)		—			768		—			814

Adjusted weighted average number of shares of common stock outstanding (3)		26,875			27,156		26,799			27,138

Earnings (loss) per common share:
Basic	$	(0.26	)	$	0.49	$	(0.60	)	$	0.59

Diluted	$	(0.26	)	$	0.48	$	(0.60	)	$	0.57

(1)

Due to a net loss, the Company excluded, for the calculation of loss per share, the effect of equity awards representing the rights to acquire 1,232 and 1,196 shares of common stock, for the three and six months ended June 30, 2011, respectively, because the effect was anti-dilutive. Stock options representing the rights to acquire 401 shares of common stock for the three and six months ended June 30, 2010, were excluded from the calculation of diluted earnings per share, because the effect was anti-dilutive after considering the exercise price of the options in comparison to the average market price, proceeds from exercise, taxes, and related unamortized compensation expense.

(2)	As of June 30, 2011 and 2010, the 1.625% convertible senior notes were not dilutive, as the average price of the Company’s stock was less than the effective conversion price of such notes, which is $62.59 per share.

(3)	Dilutive restricted stock is expected to fluctuate from quarter to quarter depending on the Company’s performance compared to a predetermined set of performance criteria. See Note 4 to these financial statements for further information regarding certain of the Company’s restricted stock.

3. Long-Term Debt

As of the dates indicated, the Company had the following outstanding long-term debt (in thousands):


	June 30, 2011		December 31, 2010
6.125% senior notes due 2014, net of original issue discount of $247 and $279	$	299,753	$	299,721
8.000% senior notes due 2017, net of original issue discount of $5,946 and $6,305		244,054		243,695
1.625% convertible senior notes due 2026, net of original issue discount of $29,478 and $35,183 (1)		220,522		214,817
Revolving credit facility due 2013		—		—

		764,329		758,233
Less current maturities		—		—

	$	764,329	$	758,233

(1)	The notes initially bear interest at a fixed rate of 1.625% per year, declining to 1.375% beginning on November 15, 2013.

The Company’s 6.125% senior notes due 2014, or 2014 senior notes, have semi-annual cash interest payments of $9.2 million due and payable each June 1 and December 1. The Company’s 8.000% senior notes due 2017, or 2017 senior notes, have semi-annual cash interest payments of $10.0 million due and payable each March 1 and September 1. The Company’s 1.625% convertible senior notes due 2026, or convertible senior notes, have

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

semi-annual cash interest payments of $2.0 million due each May 15 and November 15, declining to 1.375%, or $1.7 million semi-annually, beginning on November 15, 2013. Subject to certain conversion and redemption features of the convertible senior notes, holders of such notes may require the Company to purchase all or a portion of their notes on each of November 15, 2013, November 15, 2016 and November 15, 2021.

Under the Company’s revolving credit facility, it has the option of borrowing at a variable rate of interest equal to either (i) LIBOR, plus an applicable margin, or (ii) the greatest of the Prime Rate, the Federal Funds Effective Rate plus ¹/2 of 1% and the one-month LIBOR plus 1%, plus in each case an applicable margin. The applicable margin for each base rate is determined by a pricing grid, which is based on the Company’s leverage ratio, as defined in the credit agreement governing the amended revolving credit facility. Unused commitment fees are payable quarterly at the annual rate of 50.0 basis points of the unused portion of the borrowing base of the amended facility. As of June 30, 2011, there were no amounts drawn under the Company’s revolving credit facility and $0.9 million posted as a letter of credit. As of June 30, 2011, the Company was in compliance with all financial covenants required by its revolving credit facility.

The Company estimates the fair value of its 2014 senior notes, its 2017 senior notes and its convertible senior notes by using quoted market prices. The fair value of the Company’s revolving credit facility, when there are outstanding balances, approximates its carrying value. The face value, carrying value and fair value of the Company’s total debt was $800.0 million, $764.3 million and $789.7 million, respectively, as of June 30, 2011.

Capitalized Interest

During the three and six months ended June 30, 2010, the Company capitalized approximately $0.8 million and $3.4 million of interest costs related to the construction or conversion of vessels. No such interest was capitalized during the same periods in 2011.

4. Incentive Compensation

Stock-Based Incentive Compensation Plan

The Company’s stock-based incentive compensation plan covers a maximum of 4.2 million shares of common stock that allows the Company to grant restricted stock awards, restricted stock unit awards, or collectively restricted stock, stock options and stock appreciation rights to employees and directors.

During the six months ended June 30, 2011, the Company granted stock options, time-based and performance-based restricted stock. Time-based restricted stock was granted to directors, executive officers and certain shore-side employees of the Company.

Stock options and performance-based restricted stock were granted to executive officers of the Company. The shares to be received under the performance-based restricted stock are calculated based on the Company’s stock price performance relative to a peer group, as

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

defined by the restricted stock agreements governing such awards. Performance is measured by the change in the Company’s stock price measured against the peer group during a measurement period. The actual number of shares that could be received by the award recipients can range from 0% to 200% of the Company’s base share awards depending on the Company’s performance ranking relative to the peer group. During the six months ended June 30, 2011, the Company granted stock options, time-based restricted stock and performance-based restricted stock representing 490,587 shares, in the aggregate.

Compensation expense related to performance-based restricted stock is recognized over the service period, which is from three to five years. The fair value of the Company’s performance-based restricted stock, which is determined using a Monte Carlo simulation, is applied to the total shares that are expected to fully vest and is amortized over the vesting period based on the Company’s internal performance measured against pre-determined criteria or relative performance compared to peers, as applicable. The compensation expense related to time-based restricted stock, which is amortized over a vesting period from one to three years, is determined based on the market price of the Company’s stock on the date of grant applied to the total shares that are expected to fully vest. Compensation expense for stock options is determined using the Black-Scholes pricing model and is amortized over the vesting period of three years. In addition to the restricted stock granted in 2011, the Company granted performance-based and time-based restricted stock in 2008, 2009 and 2010. The performance-based restricted stock grants issued in 2008 were eligible for vesting in February 2011. Based on the Company’s performance, 100% of such restricted stock did not meet the performance criteria and were cancelled.

The stock-based compensation expense charges from previously issued equity grants and the financial impact such grants have on the Company’s operating results are reflected in the table below (in thousands, except for per share data):


	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
Income before taxes	$	1,725	$	2,254	$	3,926	$	4,612

Net income	$	1,116	$	1,422	$	2,536	$	2,906

Earnings per common share:
Basic	$	0.04	$	0.05	$	0.09	$	0.11

Diluted	$	0.04	$	0.05	$	0.09	$	0.11

In addition, the Company capitalized approximately $0.1 million and $0.3 million of stock-based compensation expense that related directly to newbuild construction programs and general corporate capital projects for the three and six months ended June 30, 2010, respectively. No such stock-based compensation expense was capitalized during the three and six months ended June 30, 2011.

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

5. Contingencies

In the normal course of its business, the Company becomes involved in various claims and legal proceedings in which monetary damages are sought. It is management’s opinion that the Company’s liability, if any, under such claims or proceedings would not materially affect its financial position or results of operations.

The Company insures against losses relating to its vessels, pollution and third party liabilities, including claims by employees under Section 33 of the Merchant Marine Act of 1920, or the Jones Act. Third-party liabilities and pollution claims that relate to vessel operations are covered by the Company’s entry in a mutual protection and indemnity association, or P&I Club, as well as by marine liability policies in excess of the P&I Club’s coverage. In February 2010 and 2011, the terms of entry with the P&I Club for the Downstream segment contained an annual aggregate deductible (AAD) for which the Company remains responsible. The P&I Club is responsible for covered amounts that exceed the AAD, after payment by the Company of an additional individual claim deductible. The Company provides reserves for those portions of the AAD and any individual claim deductibles for which the Company remains responsible by using an estimation process that considers Company-specific and industry data, as well as management’s experience, assumptions and consultation with outside counsel. As additional information becomes available, the Company will assess the potential liability related to its pending litigation and revise its estimates. Although historically revisions to such estimates have not been material, changes in estimates of the potential liability could materially impact the Company’s results of operations, financial position or cash flows.

6. Segment Information

The Company provides marine transportation and logistics services through two business segments. The Company primarily operates new generation offshore supply vessels, or OSVs, and multi-purpose support vessels, or MPSVs, in the U.S. Gulf of Mexico, or GoM, other U.S. coastlines, Latin America and the Middle East and operates a shore-base facility in Port Fourchon, Louisiana through its Upstream segment. The OSVs, MPSVs and the shore-base facility principally support complex exploration and production projects by transporting cargo to offshore drilling rigs and production facilities and provide support for oilfield and non-oilfield specialty services, including military applications. The Downstream segment primarily operates ocean-going tugs and tank barges in the northeastern United States, GoM, Great Lakes and Puerto Rico. The ocean-going tugs and tank barges provide coastwise transportation of refined and bunker grade petroleum products as well as non-traditional downstream services, such as support of deepwater well testing and other specialty applications for the Company’s upstream customers.

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

The following table shows reportable segment information for the three and six months ended June 30, 2011 and 2010, reconciled to consolidated totals and prepared on the same basis as the Company’s consolidated financial statements (in thousands).


	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Operating revenues:
Upstream
Domestic	$	35,188		$	85,203		$	67,758		$	149,429
Foreign (1)		32,774			15,295			61,547			27,667

		67,962			100,498			129,305			177,096

Downstream
Domestic		10,705			10,342			20,304			19,628
Foreign (1) (2)		2,150			1,045			3,475			1,407

		12,855			11,387			23,779			21,035

Total	$	80,817		$	111,885		$	153,084		$	198,131

Operating expenses:
Upstream	$	39,924		$	40,105		$	74,138		$	76,724
Downstream		8,490			8,402			15,898			16,115

Total	$	48,414		$	48,507		$	90,036		$	92,839

Depreciation:
Upstream	$	13,198		$	12,592		$	26,290		$	23,986
Downstream		2,122			2,139			4,239			4,277

Total	$	15,320		$	14,731		$	30,529		$	28,263

Amortization:
Upstream	$	3,378		$	3,475		$	7,481		$	7,160
Downstream		1,395			1,110			2,684			1,736

Total	$	4,773		$	4,585		$	10,165		$	8,896

General and administrative expenses:
Upstream	$	7,611		$	8,899		$	16,627		$	17,130
Downstream		886			741			1,734			1,431

Total	$	8,497		$	9,640		$	18,361		$	18,561

Gain on sale of assets:
Upstream	$	—		$	95		$	—		$	615
Downstream		—			—			559			4

Total	$	—		$	95		$	559		$	619

Operating income (loss):
Upstream	$	3,851		$	35,522		$	4,769		$	52,711
Downstream		(38	)		(1,005	)		(217	)		(2,520	)

Total	$	3,813		$	34,517		$	4,552		$	50,191

Capital expenditures:
Upstream	$	4,645		$	24,618		$	11,593		$	50,881
Downstream		89			134			847			1,091
Corporate		203			944			452			1,344

Total	$	4,937		$	25,696		$	12,892		$	53,316

HORNBECK OFFSHORE SERVICES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)


	As of June 30, 2011		As of December 31, 2010
Identifiable Assets:
Upstream	$	1,643,809	$	1,647,561
Downstream		213,156		205,782
Corporate		22,522		25,082

Total	$	1,879,487	$	1,878,425

Long-Lived Assets:
Upstream
Domestic	$	1,078,583	$	1,203,136
Foreign (1)		330,286		211,488

		1,408,869		1,414,624

Downstream
Domestic		149,634		166,673
Foreign (1)(2)		28,907		18,297

		178,541		184,970

Corporate		5,680		6,527

Total	$	1,593,090	$	1,606,121

(1)

The Company’s vessels conduct operations in international areas from time to time. Vessels will routinely move to and from domestic and international operating areas. As these assets are highly mobile, the long-lived assets reflected above represent the assets that were present in international areas as of June 30, 2011 and December 31, 2010, respectively.

(2)	Included are amounts applicable to the Puerto Rico downstream operations, even though Puerto Rico is considered a possession of the United States and the Jones Act applies to vessels operating in Puerto Rican waters.

Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read together with our unaudited consolidated financial statements and notes to unaudited consolidated financial statements in this Quarterly Report on Form 10-Q and our audited financial statements and notes thereto included in our Annual Report on Form 10-K as of and for the year ended December 31, 2010. This discussion contains forward-looking statements that reflect our current views with respect to future events and financial performance. Our actual results may differ materially from those anticipated in these forward-looking statements. See “Forward Looking Statements” for additional discussion regarding risks associated with forward-looking statements. In this Quarterly Report on Form 10-Q, “company,” “we,” “us,” “our” or like terms refer to Hornbeck Offshore Services, Inc. and its subsidiaries, except as otherwise indicated.

References in this Quarterly Report on Form 10-Q to “OSVs” mean offshore supply vessels; to “TTBs” mean ocean-going tugs and tank barges; to “MPSVs” mean multi-purpose support vessels; to “AHTS” mean anchor-handling towing supply; to “ROVs” mean remotely operated vehicles; to “DP-1”, “DP-2” and “DP-3” mean various classifications of dynamic positioning systems on new generation vessels to automatically maintain a vessel’s position and heading; to “flotel” mean offshore accommodations services, such as lodging, meals and office space; to “deepwater” mean offshore areas, generally 1,000’ to 5,000’ in depth; to “ultra-deepwater” mean offshore areas, generally more than 5,000’ in depth; to “deep well” mean a well drilled to a true vertical depth of 15,000’ or greater; to “new generation,” when referring to OSVs, mean modern, deepwater-capable vessels subject to the regulations promulgated under the International Convention on Tonnage Measurement of Ships, 1969, which was adopted by the United States and made effective for all U.S.-flagged vessels in 1992 and foreign-flagged equivalent vessels; and to “conventional,” when referring to OSVs, mean vessels that are at least 25 years old, are generally less than 200’ in length or carry less than 1,500 dead weight tons of cargo when originally built and primarily operate on the Continental Shelf.

General

Outlook

The on-going impact of the Department of the Interior, or the DOI’s, regulatory response to the Deepwater Horizon tragedy continues to depress the level of drilling activity in the GoM. In a recent study by IHS Global Insight and IHS CERA, it was reported that deepwater exploration and development plan approvals have dropped from a five-year annual average pace of 130 plans per year to an annualized pace of fewer than 30 plans per year as of April 10, 2011, an 80% decline. Deepwater exploration and development drilling permits have also declined by 80% from an average of nearly 160 per year to an annualized rate of 30 for 2011. The GoM is one of our primary geographic markets and drilling activity is the primary demand driver for our type of vessels in that market.

While we expect that drilling activity will gradually resume, we cannot predict if or when activity in the GoM will return to levels that existed prior to the Deepwater Horizon event and we expect that this will not occur for at least the remainder of 2011. The timing of a market

recovery will depend upon several factors outside of our control including 1) the ability of operators and drilling contractors to comply with the new rules; 2) the pace at which regulators approve plans and permit applications required by operators to drill; 3) the content of additional as yet unpromulgated rules that are expected to be issued; 4) the outcome of pending litigation brought by environmental groups challenging recent exploration plans approved by the DOI and 5) general economic conditions. These factors have adversely affected our operating results during the first half of 2011 and we expect that they will continue to do so through the second half of 2011.

In response to these events, we took measures to 1) reduce our operating costs by stacking vessels and furloughing or laying-off employees, and 2) expand our international presence by mobilizing vessels out of the GoM into foreign markets. The deployment of additional vessels to foreign markets takes time, resulting in periods in which they are not earning revenue, and requires us to make expenditures necessary for such repositioning. In addition, the ability to obtain charters in international locations is not certain given the competition that exists for such charters, which may increase as more vessels depart the GoM in response to current regulatory constraints and market conditions.

We have focused our international deployments to Mexico and Brazil, as well as other smaller foreign markets, such as Trinidad and Suriname. In order to enhance our competitiveness in Mexico, we previously re-flagged, or placed under Mexican registry, two of our older new generation U.S.-flagged vessels and placed an additional four such vessels under Mexican registry during the first half of 2011. Because we anticipate long-term growth in our Mexican and Brazilian operations, we may re-flag additional U.S.-flagged vessels into those markets. Once a U.S.-flagged vessel changes its registry and is re-flagged, it loses its eligibility to return to U.S. coastwise trade. In addition to international deployments, we will also continue to seek additional production-related, decommissioning, specialty-work or other non-oilfield markets for our vessels both in the United States and abroad. Generally, operations of these kinds are less affected by the on-going de facto regulatory moratorium in the GoM.

The de facto regulatory moratorium is adversely impacting our ability to predict or obtain utilization of our MPSVs. With the conclusion of oil spill response activities during the fourth quarter of 2010, the nature and extent of the de facto regulatory moratorium’s impact on the GoM market is now fully exposed. As a group, our MPSVs experienced a significant drop-off in demand during the first half of 2011. However, our MPSV contract coverage for the remainder of 2011 has improved as a result of recent charter activity. In July, we were awarded a three-year charter with an international oilfield service company for the HOS Iron Horse, which is expected to begin during the third quarter of 2011. As for our 370 class MPSVs, the HOS Centerline recently commenced a long-term contract with a major oil and gas company in the GoM. While several operators continue to show strong interest in utilizing our remaining two spot market MPSVs, we believe more regular and predictable utilization will be contingent upon the issuance of drilling permits in the deepwater GoM by the Bureau of Ocean Energy Management, Regulation and Enforcement, or BOEMRE. While the utilization of our 430 class MPSVs are not as directly dependent on drilling permits, these vessels are utilized for construction and other projects with long-lead times, some of which may also be impacted by the de facto regulatory moratorium. Further, our four MPSVs are all relatively new, with the first becoming available for use in October 2008 and the last becoming

available for use in March 2010. Therefore, we have not had the opportunity to have all four MPSVs working in a non-moratorium (de facto or otherwise) market environment or to fully develop the market’s understanding of their capabilities and various service offerings. This makes it difficult to predict the dayrate and utilization profile of these MPSVs under normal operating conditions and, therefore, the income generating potential that these MPSVs could have on our results of operations. Nevertheless, due to the fact that each of our MPSVs has a workload capacity and significantly higher income generating potential than each of our new generation OSVs, the utilization and dayrate levels of our MPSVs could have a very large impact on our results of operations. For this reason, our consolidated operating results, on a quarter-to-quarter basis, are disproportionately impacted by the level of dayrates and utilization achieved by our four MPSVs.

Upstream Segment

As of June 30, 2011, our 42 active new generation OSVs and four MPSVs were operating in domestic and international areas as noted in the following table:


Operating Areas
Domestic
GoM			18
Other U.S. coastlines (1)			5

			23

Foreign (2)
Latin America			20
Middle East			3

			23

Total Upstream Vessels (3)			46

(1)	Includes vessels that are currently supporting the military.

(2)	Our Upstream foreign areas of operation generally include the following countries: Brazil, Mexico, Trinidad and Qatar.

(3)	Excluded from this table are nine of our new generation OSVs and one conventional OSV that were stacked as of June 30, 2011.

Our average new generation OSV dayrates for the second quarter of 2011 were approximately $20,500 and our average OSV utilization was approximately 67.9%. OSV utilization has been significantly impacted by the lack of drilling permit activity in the GoM. With the regulatory driven demand uncertainty for the GoM Upstream market not expected to change in the near term, we have deployed additional vessels to Latin America. Our increased focus on, coupled with improving dayrates in, our core international markets (Brazil and Mexico) has resulted in improved contract coverage for the remainder of 2011. We currently have about two-thirds of our remaining new generation OSV vessel-days contracted for 2011, with 31 vessels contracted through the end of the year. Based on recently awarded contracts, we expect to have 14 Upstream vessels on charter in Brazil by the end of the third quarter of 2011. As of June 30, 2011, we had nine new generation vessels stacked, which is down from a high of 15 stacked vessels during the first quarter. Subsequent to June 30, 2011, we re-activated four stacked new generation OSVs and we expect our stacked fleet to be reduced to five vessels during the third quarter of 2011. Although we owned an average of 1.5 more new generation OSVs during the second quarter of 2011 compared to the year-ago quarter, our active new generation OSV fleet of 40.1 vessels was two fewer vessels than our

average active new generation OSV fleet for the second quarter of 2010. With the re-activation of stacked vessels, our crewing requirements have increased throughout the second quarter of 2011. We have re-hired some of our previously laid-off or furloughed crewmembers as well as hired new employees. As the global applicant pool of qualified mariners remains tight, we expect to encounter stiff competition for crewmembers, which could negatively impact our operating costs.

Downstream Segment

As of June 30, 2011, our Downstream fleet was comprised of nine double-hulled tank barges and 15 ocean-going tugs, six of which are older, lower horsepower tugs that were stacked. The prolonged weakness in the overall economy, which has impacted our Downstream segment since 2008, continues to adversely impact demand for Downstream equipment. Although Downstream results for the second quarter improved from the prior year, recent dayrate trends are roughly $5,000 below the Downstream dayrates that existed from 2006 to 2008. We anticipate that the current market conditions for our Downstream vessels will continue throughout 2011. With the protracted weak demand for tugs and tank barges coupled with the expansion of our Upstream fleet, we expect our Downstream segment to continue to represent a much smaller portion of our consolidated operating results compared to historical trends.

Critical Accounting Estimates

This Management’s Discussion and Analysis of Financial Condition and Results of Operations discusses our unaudited consolidated financial statements included in this Quarterly Report on Form 10-Q. In many cases, the accounting treatment of a particular transaction is specifically dictated by U.S. generally accepted accounting principles, or GAAP. In other circumstances, we are required to make estimates, judgments and assumptions that we believe are reasonable based on available information. We base our estimates and judgments on historical experience and various other factors that we believe are reasonable based upon the information available. Actual results may differ from these estimates under different assumptions and conditions. Our significant accounting policies are discussed in Note 2 to our consolidated financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2010.

Impairment Assessment

Our operating results for the quarter ended June 30, 2011 were consistent with our expectations given the continued lack of drilling permits issued. No new triggering events occurred during the first six months of 2011. We again considered whether the curtailed level of drilling activity in the GoM represented an indicator of impairment for any of our asset groups and concluded it did not. Some factors that the Company considered were the anticipated temporary nature of the reduced drilling activity, projected operating results over the remaining useful lives of our assets, the significant remaining operating useful lives of such assets and the mobility and flexibility of our vessels. However, should losses continue for a period of time longer than we anticipate or the current operating environment deteriorates further, we would need to re-assess whether a triggering event has occurred.

Results of Operations

The tables below set forth, by segment, the average dayrates, utilization rates and effective dayrates for certain of our vessels and the average number and size of such vessels owned during the periods indicated. These new generation OSVs and double-hulled tank barges generate the vast majority of our revenues and operating profit. Excluded from the operating data below are the results of operations for our MPSVs, conventional vessels, our shore-base facility and vessel management services.


	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Offshore Supply Vessels:
Average number of new generation OSVs (1)		51.0			49.5			51.0			49.0
Average number of active new generation OSVs (2)		40.1			42.1			38.4			41.3
Average new generation OSV fleet capacity (deadweight)		128,190			124,065			128,190			122,673
Average new generation vessel capacity (deadweight)		2,514			2,505			2,514			2,502
Average new generation OSV utilization rate (3)		67.9	%		71.8	%		63.5	%		72.3	%
Effective new generation OSV utilization rate (4)		86.3	%		84.5	%		84.4	%		85.8	%
Average new generation OSV dayrate (5)	$	20,493		$	23,874		$	20,732		$	21,946
Effective dayrate (6)	$	13,915		$	17,142		$	13,165		$	15,867
Tugs and Tank Barges:
Double-hulled tank barges:
Average number of tank barges (7)		9.0			9.0			9.0			9.0
Average fleet capacity (barrels)		884,621			884,621			884,621			884,621
Average barge capacity (barrels)		98,291			98,291			98,291			98,291
Average utilization rate (3)		90.6	%		74.2	%		86.5	%		74.7	%
Average dayrate (8)	$	17,333		$	18,708		$	16,880		$	17,262
Effective dayrate (6)	$	15,704		$	13,881		$	14,601		$	12,895

(1)

We owned 51 new generation OSVs as of June 30, 2011. Our average number of new generation OSVs for the three and six months ended June 30, 2010 reflect the deliveries of several vessels under our fourth OSV newbuild program. Excluded from this data are four multi-purpose support vessels that we own and were placed in service under our MPSV program on various dates from October 2008 to March 2010. Also excluded from this data is one stacked conventional OSV that we consider to be a non-core asset.

(2)	In response to weak market conditions, we may elect to stack certain of our new generation OSVs. Active new generation OSVs represent vessels that are fully crewed and immediately available for service during each respective period.

(3)	Utilization rates are average rates based on a 365-day year. Vessels are considered utilized when they are generating revenues.

(4)	Effective utilization rate is based on a denominator comprised only of vessel-days available for service by the active fleet, which excludes the impact of stacked vessel days.

(5)	Average dayrates represent average revenue per day, which includes charter hire, crewing services and net brokerage revenues, based on the number of days during the period that the OSVs generated revenue.

(6)	Effective dayrate represents the average dayrate multiplied by the average utilization rate.

(7)	The operating data presented above reflects only the results from our nine double-hulled tank barges. Excluded from this data are 15 ocean-going tugs owned by the Company, six of which are currently stacked.

(8)

Average dayrates represent average revenue per day, including time charters, brokerage revenue, revenues generated on a per-barrel-transported basis, demurrage, shipdocking and fuel surcharge revenue, based on the number of days during the period that the tank barges generated revenue. For purposes of brokerage arrangements, this calculation excludes that portion of revenue that is equal to the cost paid by customers of in-chartering third-party equipment.

Non-GAAP Financial Measures

We disclose and discuss EBITDA as a non-GAAP financial measure in our public releases, including quarterly earnings releases, investor conference calls and other filings with the Securities and Exchange Commission. We define EBITDA as earnings (net income) before interest, income taxes, depreciation and amortization. Our measure of EBITDA may not be comparable to similarly titled measures presented by other companies. Other companies may calculate EBITDA differently than we do, which may limit its usefulness as comparative measure.

We view EBITDA primarily as a liquidity measure and, as such, we believe that the GAAP financial measure most directly comparable to this measure is cash flows provided by operating activities. Because EBITDA is not a measure of financial performance calculated in accordance with GAAP, it should not be considered in isolation or as a substitute for operating income, net income or loss, cash flows provided by operating, investing and financing activities, or other income or cash flow statement data prepared in accordance with GAAP.

EBITDA is widely used by investors and other users of our financial statements as a supplemental financial measure that, when viewed with our GAAP results and the accompanying reconciliation, we believe provides additional information that is useful to gain an understanding of the factors and trends affecting our ability to service debt, pay deferred taxes and fund drydocking charges and other maintenance capital expenditures. We also believe the disclosure of EBITDA helps investors meaningfully evaluate and compare our cash flow generating capacity from quarter to quarter and year to year.

EBITDA is also a financial metric used by management (i) as a supplemental internal measure for planning and forecasting overall expectations and for evaluating actual results against such expectations; (ii) as a significant criteria for annual incentive cash compensation paid to our executive officers and bonuses paid to other shore-based employees; (iii) to compare to the EBITDA of other companies when evaluating potential acquisitions; and (iv) to assess our ability to service existing fixed charges and incur additional indebtedness.

The following table provides the detailed components of EBITDA as we define that term for the three and six months ended June 30, 2011 and 2010, respectively (in thousands).


	Three Months Ended June 30,						Six Months Ended June 30,
	2011			2010			2011			2010
Components of EBITDA:
Net income (loss)	$	(7,025	)	$	13,043		$	(16,061	)	$	15,598
Interest expense, net
Debt obligations		14,998			14,274			29,914			25,931
Interest income		(240	)		(155	)		(419	)		(249	)

Total interest, net		14,758			14,119			29,495			25,682

Income tax expense (benefit)		(3,839	)		7,612			(8,805	)		9,146
Depreciation		15,320			14,731			30,529			28,263
Amortization		4,773			4,585			10,165			8,896

EBITDA	$	23,987		$	54,090		$	45,323		$	87,585

The following table reconciles EBITDA to cash flows provided by operating activities for the three and six months ended June 30, 2011 and 2010, respectively (in thousands).


	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
EBITDA Reconciliation to GAAP:
EBITDA	$	23,987	$	54,090	$	45,323	$	87,585
Cash paid for deferred drydocking charges		(5,178)		(5,684)		(10,380)		(12,108)
Cash paid for interest		(11,531)		(11,289)		(21,848)		(22,316)
Cash paid for taxes		(123)		(1,628)		(499)		(2,354)
Changes in working capital		(3,924)		(5,448)		2,526		(2,761)
Stock-based compensation expense		1,725		2,254		3,926		4,612
Changes in other, net		(580)		(34)		709		(770)

Net cash flows provided by operating activities	$	4,376	$	32,261	$	19,757	$	51,888

In addition, we also make certain adjustments to EBITDA for losses on early extinguishment of debt, if any, stock-based compensation expense and interest income to compute ratios used in certain financial covenants of our revolving credit facility with various lenders. We believe that these ratios are a material component of certain financial covenants in such credit agreements and failure to comply with the financial covenants could result in the acceleration of indebtedness or the imposition of restrictions on our financial flexibility.

The following table provides certain detailed adjustments to EBITDA, as defined in our revolving credit facility, for the three and six months ended June 30, 2011 and 2010, respectively (in thousands).

Adjustments to EBITDA for Computation of Financial Ratios Used in Debt Covenants


	Three Months Ended June 30,				Six Months Ended June 30,
	2011		2010		2011		2010
Stock-based compensation expense	$	1,725	$	2,254	$	3,926	$	4,612
Interest income		240		155		419		249

Set forth below are the material limitations associated with using EBITDA as a non-GAAP financial measure compared to cash flows provided by operating activities.

•

EBITDA does not reflect the future capital expenditure requirements that may be necessary to replace our existing vessels as a result of normal wear and tear,

•

EBITDA does not reflect the interest, future principal payments and other financing-related charges necessary to service the debt that we have incurred in acquiring and constructing our vessels,

•

EBITDA does not reflect the deferred income taxes that we will eventually have to pay once we are no longer in an overall tax net operating loss carryforward position, as applicable, and

•

EBITDA does not reflect changes in our net working capital position.

Management compensates for the above-described limitations in using EBITDA as a non-GAAP financial measure by only using EBITDA to supplement our GAAP results.

Summarized financial information concerning our reportable segments for the three months ended June 30, 2011 and 2010, respectively, is shown below in the following table (in thousands, except percentage changes):


	Three Months Ended June 30,						Increase (Decrease)
	2011			2010			$ Change			% Change
Revenues:
Upstream
Domestic	$	35,188		$	85,203		$	(50,015	)		(58.7	)%
Foreign		32,774			15,295			17,479			>100.0

		67,962			100,498			(32,536	)		(32.4	)

Downstream
Domestic		10,705			10,342			363			3.5
Foreign (1)		2,150			1,045			1,105			>100.0

		12,855			11,387			1,468			12.9

	$	80,817		$	111,885		$	(31,068	)		(27.8	)%

Operating expenses:
Upstream	$	39,924		$	40,105		$	(181	)		(0.5	)%
Downstream		8,490			8,402			88			1.0

	$	48,414		$	48,507		$	(93	)		(0.2	)%

Depreciation and amortization:
Upstream	$	16,576		$	16,067		$	509			3.2	%
Downstream		3,517			3,249			268			8.2

	$	20,093		$	19,316		$	777			4.0	%

General and administrative expenses:
Upstream	$	7,611		$	8,899		$	(1,288	)		(14.5	)%
Downstream		886			741			145			19.6

	$	8,497		$	9,640		$	(1,143	)		(11.9	)%

Gain (loss) on sale of assets:
Upstream	$	—		$	95		$	(95	)		(100.0	)%
Downstream		—			—			—			—

	$	—		$	95		$	(95	)		(100.0	)%

Operating income (loss):
Upstream	$	3,851		$	35,522		$	(31,671	)		(89.2	)%
Downstream		(38	)		(1,005	)		967			96.2

	$	3,813		$	34,517		$	(30,704	)		(89.0	)%

Interest expense	$	14,998		$	14,274		$	724			5.1	%

Interest income	$	240		$	155		$	85			54.8	%

Income tax expense (benefit)	$	(3,839	)	$	7,612		$	(11,451	)		(>100.0	)%

Net income (loss)	$	(7,025	)	$	13,043		$	(20,068	)		(>100.0	)%

(1)	Included are the amounts applicable to our Puerto Rico Downstream operations, even though Puerto Rico is considered a possession of the United States and the Jones Act applies to vessels operating in Puerto Rican waters.

Three Months Ended June 30, 2011 Compared to Three Months Ended June 30, 2010

Revenues. Revenues for the three months ended June 30, 2011 decreased by $31.1 million, or 27.8%, to $80.8 million compared to the same period in 2010 primarily due to the lack of drilling activity in the GoM, which led to our decision to stack certain new generation OSVs. Our weighted-average active operating fleet as of June 30, 2011 was approximately 62 vessels compared to 65 vessels as of June 30, 2010.

Revenues from our Upstream segment decreased by $32.5 million, or 32.4%, to $68.0 million for the three months ended June 30, 2011 compared to $100.5 million for the same period in 2010. These lower revenues primarily resulted from a decline in activity from new generation OSVs and MPSVs that were in-service during each of the quarters ended June 30, 2011 and 2010 and the stacking of certain new generation OSVs in response to regulatory-driven demand weakness in the GoM. These lower revenues were partially offset by incremental revenues related to vessels operating in Latin America. Our new generation OSV average dayrates were $20,493 for the second quarter of 2011 compared to $23,874 for the same period in 2010, a decrease of $3,381, or 14.2%. Our new generation OSV dayrates for the second quarter of 2010 were favorably impacted by non-recurring revenues for one of our specialty service vessels unrelated to the oil spill relief efforts in the GoM. Excluding these revenues, our new generation OSV dayrates would have been $20,628. Our new generation OSV utilization was 67.9% for the second quarter of 2011 compared to 71.8% for the same period in 2010. The decrease in utilization was largely due to having an average of 10.9 vessels stacked during the three months ended June 30, 2011 compared to an average of 7.4 stacked vessels during the prior-year period. Domestic revenues for our Upstream segment decreased $50.0 million during the three months ended June 30, 2011 due to reduced drilling activity in the GoM. Foreign revenues for our Upstream segment increased $17.5 million, or 114.3%, primarily due to an average of 11 additional vessels deployed to Latin America since June 30, 2010. Foreign revenues comprised 48.2% of our total Upstream revenues compared to 15.2% for the year-ago quarter. This trend of higher foreign revenues is expected to continue throughout the second half of 2011, particularly in recognition of the eight vessels that were recently awarded contracts in Latin America commencing during 2011.

Revenues from our Downstream segment increased by $1.5 million, or 12.9%, to $12.9 million for the three months ended June 30, 2011 compared to the three months ended June 30, 2010. This revenue increase was largely due to higher contract of affreightment (COA) dayrates and strong utilization for our clean petroleum product (CPP) barges in the Northeast U.S. market and, to a lesser extent, demand for our dirty petroleum (DPP) barges in the GoM. Our double-hulled tank barge average dayrates were $17,333 for the three months ended June 30, 2011, a decrease of $1,375, or 7.3%, from $18,708 for the same period in 2010. Tank barge dayrates in the prior-year quarter were favorably impacted by well-test services performed for an Upstream customer. Excluding the impact of the well-test project, dayrates would have been $17,547, for the prior-year quarter. Our double-hulled tank barge utilization was 90.6% for the second quarter of 2011 compared to 74.2% for the second quarter of 2010. Effective, or utilization-adjusted, dayates for our double-hulled tank barges were $15,704 for the three months ended June 30, 2011, which was $2,684, or 20.6%, higher than the prior-year quarter effective dayrates, as adjusted to exclude the 2010 well-test project.

Operating Expenses. Operating expenses for the three months ended June 30, 2011 decreased by $0.1 million, or 0.2%, to $48.4 million. This slight decrease was primarily associated with the reduction of our active operating fleet compared to the year-ago period.

Operating expenses for our Upstream segment were $39.9 million, a decrease of $0.2 million, or 0.5%, for the second quarter of 2011 compared to $40.1 million for the same period in 2010. Operating expenses for our Upstream segment were driven lower due to reduced activity for vessels that comprise our MPSV fleet and an increase in the average number of stacked new generation OSVs since late 2010. This favorable variance was partially offset by higher operating expenses for our vessels working in Latin America and costs incurred to pre-position additional vessels that are mobilizing for long-term contracts in Latin America, which are expected to commence during the second half of 2011.

Operating expenses for our Downstream segment were $8.5 million, an increase of $0.1 million, or 1.0%, for the three months ended June 30, 2011 compared to $8.4 million for the same period in 2010. The slight increase in operating expenses is largely the result of having a greater mix of Downstream vessels operating under COA agreements instead of time charters. Under COA arrangements, the vessel owner typically bears the cost of fuel. These increases were partially offset by reduced expenses associated with vessels that have been sold since June 30, 2010.

Depreciation and Amortization. Depreciation and amortization was $0.8 million higher for the three months ended June 30, 2011 compared to the same period in 2010 primarily due to incremental depreciation expense related to vessels placed in service under our fourth OSV newbuild program and our MPSV program on various dates during 2010. Depreciation and amortization expense is expected to increase further when these and any other recently acquired and newly constructed vessels undergo their initial 30-month and 60-month recertifications.

General and Administrative Expenses. General and administrative expenses of $8.5 million, or 10.5% of revenues, decreased by $1.1 million during the three months ended June 30, 2011 compared to the three months ended June 30, 2010. This decrease in G&A expenses were primarily attributable to lower shoreside personnel expenses and a reduction in bad debt reserves. The reduction of bad debt reserves resulted from recent collections activity related to foreign customer billings and billings for oil spill remediation efforts in late 2010. Our general and administrative expenses are expected to remain in the approximate annual range of $35 million to $39 million for the year ending December 31, 2011.

Operating Income. Operating income decreased by $30.7 million to $3.8 million during the three months ended June 30, 2011 compared to the same period in 2010 due to the reasons discussed above. Operating income as a percentage of revenues for our Upstream segment was 5.7% for the three months ended June 30, 2011 compared to 35.3% for the same period in 2010.

Interest Expense. Interest expense increased $0.7 million during the three months ended June 30, 2011 compared to the same period in 2010. Lower capitalized interest from having fewer vessels under construction or conversion was the primary reason that our interest expense increased from the prior-year quarter. During the second quarter of 2011, we did not

capitalize any construction period interest compared to capitalized interest of $0.8 million, or roughly 5% of our total interest costs, for the year-ago quarter.

Interest Income. Interest income increased $0.1 million during the three months ended June 30, 2011 compared to the same period in 2010. Our average cash balance increased to $141.8 million for the three months ended June 30, 2011 compared to $49.2 million for the same period in 2010. The average interest rate earned on our invested cash balances during the three months ended June 30, 2011 was approximately 0.5% compared to 0.8% for the same period in 2010.

Income Tax Expense (Benefit). Our effective tax rate was 35.3% and 36.9% for the three months ended June 30, 2011 and 2010, respectively. Our income tax expense (benefit) primarily consists of deferred taxes. Our income tax rate is higher than the federal statutory rate primarily due to expected state tax liabilities and items not deductible for federal income tax purposes.

Net Income (Loss). Operating performance decreased year-over-year by $20.1 million for a reported net loss of $7.0 million for the three months ended June 30, 2011. The net loss incurred for the second quarter of 2011 was primarily due to a decrease in operating income discussed above and a $0.6 million pre-tax increase in net interest expense.

Summarized financial information concerning our reportable segments for the six months ended June 30, 2011 and 2010, respectively, is shown below in the following table (in thousands, except percentage changes):


	Six Months Ended June 30,						Increase (Decrease)
	2011			2010			$ Change			% Change
Revenues:
Upstream
Domestic	$	67,758		$	149,429		$	(81,671)			(54.7	)%
Foreign		61,547			27,667			33,880			>100.0

		129,305			177,096			(47,791	)		(27.0	)

Downstream
Domestic		20,304			19,628			676			3.4
Foreign (1)		3,475			1,407			2,068			>100.0

		23,779			21,035			2,744			13.0

	$	153,084		$	198,131		$	(45,047	)		(22.7	)%

Operating expenses:
Upstream	$	74,138		$	76,724		$	(2,586	)		(3.4	)%
Downstream		15,898			16,115			(217	)		(1.3	)

	$	90,036		$	92,839		$	(2,803	)		(3.0	)%

Depreciation and amortization:
Upstream	$	33,771		$	31,146		$	2,625			8.4	%
Downstream		6,923			6,013			910			15.1

	$	40,694		$	37,159		$	3,535			9.5	%

General and administrative expenses:
Upstream	$	16,627		$	17,130		$	(503	)		(2.9	)%
Downstream		1,734			1,431			303			21.2

	$	18,361		$	18,561		$	(200	)		(1.1	)%

Gain on sale of assets:
Upstream	$	—		$	615		$	(615	)		(100.0	)%
Downstream		559			4			555			>100.0

	$	559		$	619		$	(60	)		(9.7	)%

Operating income (loss):
Upstream	$	4,769		$	52,711		$	(47,942	)		(91.0	)%
Downstream		(217	)		(2,520	)		2,303			(91.4	)

	$	4,552		$	50,191		$	(45,639	)		(90.9	)%

Interest expense	$	29,914		$	25,931		$	3,983			15.4	%

Interest income	$	419		$	249		$	170			68.3	%

Income tax expense (benefit)	$	(8,805	)	$	9,146		$	(17,951	)		(>100.0	)%

Net income (loss)	$	(16,061	)	$	15,598		$	(31,659	)		(>100.0	)%

(1)	Included are the amounts applicable to our Puerto Rico Downstream operations, even though Puerto Rico is considered a possession of the United States and the Jones Act applies to vessels operating in Puerto Rican waters.

Six Months Ended June 30, 2011 Compared to Six Months Ended June 30, 2010

Revenues. Revenues for the six months ended June 30, 2011 decreased by $45.0 million, or 22.7%, to $153.1 million compared to the same period in 2010 primarily due to the lack of drilling activity in the GoM, which led to our decision to stack certain new generation OSVs. Our weighted-average active operating fleet as of June 30, 2011 was approximately 60 vessels compared to 64 vessels as of June 30, 2010.

Revenues from our Upstream segment decreased by $47.8 million, or 27.0%, to $129.3 million for the six months ended June 30, 2011 compared to $177.1 million for the same period in 2010. These lower revenues primarily resulted from a decline in activity from new generation OSVs and MPSVs that were in-service during each of the quarters ended June 30, 2011 and 2010 and the stacking of certain new generation OSVs in primary response to regulatory-driven demand weakness in the GoM. These lower revenues were partially offset by incremental revenues related to vessels operating in Latin America and, to a lesser degree, contributions from vessels added to the Upstream fleet in 2010 through our fourth OSV newbuild program. Our new generation OSV average dayrates were $20,732 for the first six months of 2011 compared to $21,946 for the same period in 2010, a decrease of $1,214, or 5.5%. Our new generation OSV dayrates for the first six months of 2010 were favorably impacted by non-recurring revenues for one of our specialty service vessels unrelated to the oil spill relief efforts in the GoM. Excluding these revenues, our new generation OSV dayrates would have been $20,310, or 2.1% lower than the six months ended June 30, 2011. Our new generation OSV utilization was 63.5% for the first six months of 2011 compared to 72.3% for the same period in 2010. The decrease in utilization was largely due to having an average of 12.6 vessels stacked during the six months ended June 30, 2011 compared to an average of 7.7 stacked vessels during the prior-year period. Domestic revenues for our Upstream segment decreased $81.7 million during the six months ended June 30, 2011 due to reduced drilling activity in the GoM. Foreign revenues for our Upstream segment increased $33.9 million primarily due to an average of ten additional vessels deployed to Latin America since June 30, 2010. Foreign revenues comprised 47.6% of our total Upstream revenues compared to 15.6% for the first six months of 2010. This trend of higher foreign revenues is expected to continue throughout the second half of 2011, particularly in recognition of the eight vessels that were recently awarded contracts in Latin America commencing during 2011.

Revenues from our Downstream segment increased by $2.7 million, or 13.0%, to $23.8 million for the six months ended June 30, 2011 compared to the six months ended June 30, 2010. This revenue increase was due to higher effective dayrates earned during the first six months of 2011 compared to the same period in 2010. Our double-hulled tank barge average dayrates were $16,880 for the six months ended June 30, 2011, a decrease of $382, or 2.2%, from $17,262 for the same period in 2010. Our double-hulled tank barge utilization was 86.5% for the first half of 2011 compared to 74.7% for the first half of 2010.

Operating Expenses. Operating expenses for the six months ended June 30, 2011 decreased by $2.8 million, or 3.0%, to $90.0 million. This decrease was primarily associated with the reduction of our active operating fleet compared to the year-ago period partially offset by higher operating costs for vessels operating in international regions.

Operating expenses for our Upstream segment were $74.1 million, a decrease of $2.6 million, or 3.4%, for the six months ended June 30, 2011 compared to $76.7 million for the

same period in 2010. Operating expenses for our Upstream segment were driven lower by reduced activity for vessels that comprise our MPSV fleet and an increase in the average number of stacked new generation OSVs since late 2010. This favorable variance was partially offset by higher operating expenses for our vessels working in Latin America and incremental costs incurred for vessels that were placed in service during 2010 under our fourth OSV newbuild program.

Operating expenses for our Downstream segment were $15.9 million, a decrease of $0.2 million, or 1.3%, for the six months ended June 30, 2011 compared to $16.1 million for the same period in 2010. The decrease in operating expenses for the Downstream segment is attributable to the sale of seven vessels in our Downstream fleet since June 30, 2010.

Depreciation and Amortization. Depreciation and amortization was $3.5 million higher for the six months ended June 30, 2011 compared to the same period in 2010. This increase is primarily due to incremental depreciation expense related to vessels placed in service under our fourth OSV newbuild program and our MPSV program during 2010. In addition, amortization expense was higher in the current period for vessels undergoing their initial recertifications that have been placed in-service on various dates since 2008. Depreciation and amortization expense is expected to increase further as these and any other recently acquired and newly constructed vessels undergo their initial 30-month and 60-month recertifications.

General and Administrative Expenses. General and administrative expenses of $18.4 million, or 12.0% of revenues, decreased by $0.2 million during the six months ended June 30, 2011 compared to the six months ended June 30, 2010. This decrease in G&A expenses were primarily the result of lower personnel and stock-based compensation expense, which was partially offset by higher reserves associated with oil spill response-related receivables and a greater concentration of foreign-sourced customer billings. Our general and administrative expenses are expected to remain in the approximate annual range of $35 million to $39 million for the year ending December 31, 2011.

Gain on Sale of Assets. During the first six months of 2011, we sold four single-hulled tank barges for net cash proceeds of $2.1 million, which resulted in aggregate gains of approximately $0.6 million ($0.4 million after tax or $0.01 per diluted share). During the first six months of 2010, we sold one conventional OSV for net cash proceeds of $1.3 million and recorded a gain of approximately $0.5 million ($0.3 million after tax or $0.01 per diluted share).

Operating Income. Operating income decreased by $45.6 million to $4.6 million during the six months ended June 30, 2011 compared to the same period in 2010 due to the reasons discussed above. Operating income as a percentage of revenues for our Upstream segment was 3.7% for the six months ended June 30, 2011 compared to 29.8% for the same period in 2010.

Interest Expense. Interest expense increased $4.0 million during the six months ended June 30, 2011 compared to the same period in 2010. Lower capitalized interest from having fewer vessels under construction or conversion was the primary reason that our interest expense increased from the same period in 2010. During the first six months of 2011, we did

not capitalize any construction period interest compared to capitalized interest of $3.4 million, or roughly 12% of our total interest costs, for the year-ago period.

Interest Income. Interest income increased $0.2 million during the six months ended June 30, 2011 compared to the same period in 2010. Our average cash balance increased to $140.4 million for the six months ended June 30, 2011 compared to $52.0 million for the same period in 2010. The average interest rate earned on our invested cash balances during the six months ended June 30, 2011 was approximately 0.5% compared to 0.8% for the same period in 2010.

Income Tax Expense (Benefit). Our effective tax rate was 35.4% and 37.0% for the six months ended June 30, 2011 and 2010, respectively. Our income tax expense (benefit) primarily consists of deferred taxes. Our income tax rate is higher than the federal statutory rate primarily due to expected state tax liabilities and items not deductible for federal income tax purposes.

Net Income (Loss). Operating performance decreased year-over-year by $31.7 million for a reported net loss of $16.1 million for the six months ended June 30, 2011. The net loss incurred for the first six months of 2011 was primarily due to a decrease in operating income discussed above and a $3.8 million pre-tax increase in net interest expense.

Liquidity and Capital Resources

Our capital requirements have historically been financed with cash flows from operations, proceeds from issuances of our debt and common equity securities, borrowings under our credit facilities and cash received from the sale of assets. We require capital to fund on-going operations, vessel recertifications, discretionary capital expenditures and debt service and may require capital to fund potential future vessel construction, retrofit or conversion projects or acquisitions. The nature of our capital requirements and the types of our financing sources are not expected to change significantly for the remainder of 2011. While we have postponed required drydockings for some of our stacked vessels, we will be required to conduct any deferred drydockings prior to such vessels returning to service. The drydocking funds required to recertify currently stacked vessels will be dependent upon vessel class, certification requirements and the timing and sustainability of any market recovery.

We have reviewed all of our debt agreements as well as our liquidity position and projected future cash needs. Despite volatility in financial and commodity markets, we remain confident in our current financial position, the strength of our balance sheet and the short- and long-term viability of our business model. To date, our liquidity has not been materially impacted and we do not expect that it will be materially impacted in the near-future due to such volatility. We believe that our cash on-hand, projected operating cash flow and available borrowing capacity under our recently amended revolving credit facility will be more than sufficient to operate the Company, while we reposition vessels to alternative markets and/or await the resumption of drilling activities in the GoM.

Although we expect to continue generating positive working capital through our operations, events beyond our control, such as an extended delay in returning to normal operating conditions following the de facto regulatory moratorium in the GoM, declines in

expenditures for exploration, development and production activity, mild winter conditions or any extended reduction in domestic consumption of refined petroleum products and other reasons discussed in the Risk Factors in our Annual Report on Form 10-K or under the “Forward Looking Statements” discussed in this Quarterly Report on Form 10-Q, may affect our financial condition or results of operations. None of our funded debt instruments mature any sooner than November 2013; however, our currently undrawn revolving credit facility matures March 2013. Depending on the market demand for our vessels, long-term debt maturities and other growth opportunities that may arise, we may require additional debt or equity financing. We currently expect to generate sufficient cash to re-pay our long-term debt upon maturity. However, it is possible that, due to events beyond our control, including those described in our Risk Factors, should such need for additional financing arise, we may not be able to access the capital markets on attractive terms at that time or otherwise obtain sufficient capital to meet our maturing debt obligations or finance growth opportunities that may arise. We will continue to closely monitor our liquidity position, as well as the state of the global capital and credit markets.

As of June 30, 2011, we had total cash and cash equivalents of $136.5 million. Excluding any potential cash requirements for growth opportunities that may arise, our current cash on-hand and our internal cash projections indicate that our $250 million revolving credit facility will remain undrawn for the foreseeable future beyond 2011. As of June 30, 2011, we had a posted letter of credit for $0.9 million and have $249.1 million of credit available under our revolving credit facility, for all uses of proceeds, including working capital, if necessary.

Cash Flows

Operating Activities. We rely primarily on cash flows from operations to provide working capital for current and future operations. Cash flows from operating activities were $19.8 million for the six months ended June 30, 2011 and $51.9 million for the six months ended June 30, 2010. Operating cash flows for the first six months of 2011 were unfavorably affected by a decline in our weighted-average operating fleet and a decrease in demand for our Upstream equipment primarily due to regulatory-driven market weakness in the GoM.

Investing Activities. Net cash used in investing activities was $10.8 million for the six months ended June 30, 2011 and $51.9 million for the six months ended June 30, 2010. Cash utilized during the first six months of 2011 primarily consisted of capital improvements made to our operating fleet, which were partially offset by approximately $2.1 million in aggregate net cash proceeds from the sale of four single-hulled tank barges. Cash utilized during the first six months of 2010 primarily consisted of construction costs incurred for our newbuild and conversion programs, which were partially offset by approximately $1.5 million in aggregate net cash proceeds from the sale of one conventional OSV and other non-revenue generating equipment. Our fourth new generation OSV program and our MPSV program were completed during 2010.

Financing Activities. Net cash provided by financing activities was $0.6 million for the six months ended June 30, 2011 and $0.7 million for the six months ended June 30, 2010. Net cash provided for six months ended June 30, 2010 and 2011 was comprised of deferred financing costs and net proceeds from common shares issued pursuant to our employee stock-based compensation plans.

Contractual Obligations

Debt

As of June 30, 2011, we had total debt of $764.3 million, net of original issue discount of $35.7 million. Our debt is comprised of $299.8 million of our 6.125% senior notes due 2014, or 2014 senior notes, $244.1 million of our 8.000% senior notes due 2017, or 2017 senior notes, and $220.5 million of our 1.625% convertible senior notes due 2026, or convertible senior notes. On March 14, 2011, we amended the credit agreement governing our $250 million revolving credit facility to adjust certain financial ratios and provide for additional new maintenance covenants. The revolving credit facility as of July 31, 2011 remains undrawn. The changes to our revolving credit facility were effective commencing with the fiscal quarter ended December 31, 2010. Other than these changes, all other definitions and substantive terms in our credit agreement governing our revolving credit facility were unchanged. For further information on our debt agreements, see Note 3 to our consolidated financial statements included herein. As of June 30, 2011, we were in compliance with all of our debt covenants.

The credit agreement governing our revolving credit facility and the indentures governing our 2014 senior notes and 2017 senior notes impose certain operating and financial restrictions on us. Such restrictions affect, and in many cases limit or prohibit, among other things, our ability to incur additional indebtedness, make capital expenditures, redeem equity, create liens, sell assets and make dividend or other restricted payments. Based on our recently amended financial ratios for the quarterly compliance reporting period ended June 30, 2011, the full amount of the undrawn borrowing base under our revolving credit facility is available to us for all uses of proceeds, including working capital, if necessary. We continuously review our debt covenants and report our compliance with financial ratios on a quarterly basis. We also consider such covenants in evaluating transactions that will have an effect on our financial ratios.

Capital Expenditures and Related Commitments

The following table summarizes the costs incurred, prior to the allocation of construction period interest, for maintenance capital expenditures for the three and six months ended June 30, 2011 and 2010, and a forecast for fiscal 2011 (in millions):


	Three Months Ended June 30,				Six Months Ended June 30,				Year Ended December 31, 2011
	2011		2010		2011		2010		Year Ended December 31, 2011
	*Actual*		*Actual*		*Actual*		*Actual*		*Forecast*
Maintenance and Other Capital Expenditures:
Maintenance Capital Expenditures
Deferred drydocking charges (1)	$	5.2	$	5.7	$	10.4	$	12.1	$	24.7
Other vessel capital improvements (2)		2.4		1.0		6.4		4.6		18.7

		7.6		6.7		16.8		16.7		43.4

Other Capital Expenditures
Commercial-related vessel improvements (3)		2.2		14.7		5.8		16.2		24.3
Miscellaneous non-vessel additions (4)		0.3		0.9		0.7		1.3		2.7

		2.5		15.6		6.5		17.5		27.0

Total:	$	10.1	$	22.3	$	23.3	$	34.2	$	70.4

(1)	Deferred drydocking charges for the full-year 2011 include the projected recertification costs for 17 OSVs, one MPSV, two tank barges and two tugs.

(2)	Other vessel capital improvements include costs for discretionary vessel enhancements, which are typically incurred during a planned drydocking event to meet customer specifications

(3)	Commercial-related vessel improvements include items, such as cranes, ROVs and other specialized vessel equipment, which costs are typically included in and offset by higher dayrates charged to customers.

(4)	Non-vessel capital expenditures are primarily related to information technology and shore-side support initiatives.

Forward Looking Statements

This Quarterly Report on Form 10-Q contains “forward-looking statements,” as contemplated by the Private Securities Litigation Reform Act of 1995, in which the Company discusses factors it believes may affect its performance in the future. Forward-looking statements are all statements other than historical facts, such as statements regarding assumptions, expectations, beliefs and projections about future events or conditions. You can generally identify forward-looking statements by the appearance in such a statement of words like “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “project,” “remain,” “should,” or “will,” or other comparable words or the negative of such words. The accuracy of the Company’s assumptions, expectations, beliefs and projections depends on events or conditions that change over time and are thus susceptible to change based on actual experience, new developments and known and unknown risks. The Company gives no assurance that the forward-looking statements will prove to be correct and does not undertake any duty to update them. The Company’s actual future results might differ from the forward-looking statements made in this Quarterly Report on Form 10-Q for a variety of reasons, including the effect of the de facto regulatory moratorium on the issuance of drilling and other permits in the GoM due to government regulations. Future results may also be impacted by proposed federal legislation or regulations that are being and may yet be implemented in response to the Deepwater Horizon event, as well as the outcome of pending litigation brought by environmental groups challenging recent exploration plans approved by the DOI. Such legislation, regulations or litigation could further aggravate a number of other existing risks, uncertainties and assumptions, including, without limitation: less than anticipated success in marketing and operating the Company’s MPSVs; bureaucratic, administrative or operating barriers that delay vessels chartered in foreign markets from going on-hire or result in contractual penalties imposed by foreign customers; further weakening of demand for the Company’s services; the inability to effectively curtail operating expenses from stacked vessels; unplanned customer suspensions, cancellations, rate reductions or non-renewals of vessel charters or failures to finalize commitments to charter vessels; industry risks; further reductions in capital spending budgets by customers; declines in oil and natural gas prices; increases in operating costs; the inability to accurately predict vessel utilization levels and dayrates; the inability to effectively compete in or operate in international markets; less than anticipated subsea infrastructure demand activity in the U.S. Gulf of Mexico and other markets; the level of fleet additions by competitors that could result in over capacity; economic and political risks, including the recent unrest in the Middle East; weather related risks; the inability to attract and retain qualified personnel; regulatory risks; the repeal or administrative weakening of the Jones Act, including any changes in the interpretation of the Jones Act related to the U.S. citizenship qualification; the imposition of laws or regulations that result in reduced exploration and production activities or that increase the Company’s operating costs or operating requirements, including any such laws or regulations that may arise as a result of the de facto

regulatory moratorium or as a result of the oil spill disaster in the Gulf of Mexico; drydocking delays and cost overruns and related risks; vessel accidents or pollution incidents resulting in lost revenue or expenses that are unrecoverable from insurance policies or other third parties; unexpected litigation and insurance expenses; fluctuations in foreign currency valuations compared to the U.S. dollar and risks associated with expanded foreign operations, such as non-compliance with or the unanticipated effect of tax laws, customs laws, immigration laws, or other legislation that result in higher than anticipated tax rates or other costs or the inability to repatriate foreign-sourced earnings and profits. In addition, the Company’s future results may be impacted by adverse economic conditions, such as inflation, deflation, or lack of liquidity in the capital markets, that may negatively affect it or parties with whom it does business. Should one or more of the foregoing risks or uncertainties materialize in a way that negatively impacts the Company, or should the Company’s underlying assumptions prove incorrect, the Company’s actual results may vary materially from those anticipated in its forward-looking statements, and its business, financial condition and results of operations could be materially and adversely affected. Additional factors that you should consider are set forth in detail in the “Risk Factors” section of this Quarterly Report on Form 10-Q as well as other filings the Company has made and will make with the Securities and Exchange Commission which, after their filing, can be found on the Company’s website www.hornbeckoffshore.com.

Item 3—Quantitative and Qualitative Disclosures About Market Risk

There have been no material changes to the market risk disclosures set forth in Item 7A in our Annual Report on Form 10-K for the year ended December 31, 2010.

Item 4—Controls and Procedures

Disclosure Controls and Procedures

Our management, with the participation of our Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of our disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) as of the end of the period covered by this report. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that, as of the end of such period, our disclosure controls and procedures were effective to ensure that information required to be disclosed by us in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosures.

Changes in Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting that occurred during the quarter ended June 30, 2011 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II—OTHER INFORMATION

Item 1—Legal Proceedings

None.

Item 1A—Risk Factors

There were no changes to the risk factors previously disclosed in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2010.

Item 2—Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3—Defaults Upon Senior Securities

None.

Item 4—Removed and Reserved

Item 5—Other Information

None.

Item 6—Exhibits

Exhibit Index


Exhibit Number		Description of Exhibit
3.1	—	Second Restated Certificate of Incorporation of the Company, as amended (incorporated by reference to Exhibit 3.1 to the Company’s Form 10-Q for the quarter ended March 31, 2005).

3.2	—	Certificate of Designation of Series A Junior Participating Preferred Stock filed with the Secretary of State of the State of Delaware on June 20, 2003 (incorporated by reference to Exhibit 3.6 to the Company’s Registration Statement on Form S-1 dated September 19, 2003, Registration No. 333-108943).

3.3	—	Fourth Restated Bylaws of the Company adopted June 30, 2004 (incorporated by reference to Exhibit 3.3 to the Company’s Form 10-Q for the quarter ended June 30, 2004).

4.1	—	Indenture dated as of November 23, 2004 between the Company, the guarantors named therein and Wells Fargo Bank, National Association (as Trustee), including table of contents and cross-reference sheet (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed November 24, 2004).


Exhibit Number		Description of Exhibit
4.2	—	Specimen 6.125% Series B Senior Note due 2014 (incorporated by reference to Exhibit 4.12 to the Company’s Registration Statement on Form S-4 dated December 22, 2004, Registration No. 333-121557).

4.3	—	Specimen stock certificate for the Company’s common stock, $0.01 par value (incorporated by reference to Exhibit 4.2 to the Company’s Registration Statement on Form 8-A dated March 25, 2004, Registration No. 001-32108).

4.4	—	Rights Agreement dated as of June 18, 2003 between the Company and Mellon Investor Services LLC as Rights Agent, which includes as Exhibit A the Certificate of Designations of Series A Junior Participating Preferred Stock, as Exhibit B the form of Right Certificate and as Exhibit C the form of Summary of Rights to Purchase Stock (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed July 3, 2003).

4.5	—	Amendment to Rights Agreement dated as of March 5, 2004 between the Company and Mellon Investor Services LLC as Rights Agent (incorporated by reference to Exhibit 4.13 to the Company’s Form 10-K for the period ended December 31, 2003).

4.6	—	Second Amendment to Rights Agreement dated as of September 3, 2004 by and between the Company and Mellon Investor Services, LLC as Rights Agent (incorporated by reference to Exhibit 4.3 to the Company’s Form 8-A/A filed September 3, 2004, Registration No. 001-32108).

4.7	—	Indenture dated as of November 13, 2006 by and among Hornbeck Offshore Services, Inc., the guarantors named therein, and Wells Fargo Bank, National Association, as Trustee (including form of 1.625% Convertible Senior Notes due 2026) (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed November 13, 2006).

4.8	—	Confirmation of OTC Warrant Confirmation dated as of November 7, 2006 by and between Hornbeck Offshore Services, Inc. and Jefferies International Limited (incorporated by reference to Exhibit 4.6 to the Company’s Current Report on Form 8-K filed November 13, 2006).

4.9	—	Confirmation of OTC Warrant Confirmation dated as of November 7, 2006 by and between Hornbeck Offshore Services, Inc and Bear, Stearns International Limited, as supplemented on November 9, 2006 (incorporated by reference to Exhibit 4.7 to the Company’s Current Report on Form 8-K filed November 13, 2006).

4.10	—	Confirmation of OTC Warrant Confirmation dated as of November 7, 2006 by and between Hornbeck Offshore Services, Inc. and AIG-FP Structured Finance (Cayman) Limited, as supplemented on November 9, 2006 (incorporated by reference to Exhibit 4.8 to the Company’s Current Report on Form 8-K filed November 13, 2006).


Exhibit Number		Description of Exhibit
4.11	—	Indenture dated as of August 17, 2009 by and among Hornbeck Offshore Services, Inc., the guarantors named therein, and Wells Fargo Bank, National Association, as Trustee (including form of 8% Senior Notes due 2017) (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed August 18, 2009).

4.12	—	Specimen 8% Series B Senior Note due 2017 (incorporated by reference to Exhibit 4.11 to the Company’s Registration Statement on Form S-4 dated September 29, 2009, Registration No. 333-162197).

*10.1	—	Employment Agreement dated effective January 1, 2011 by and between Samuel A. Giberga and the Company.

*31.1	—	Certification of the Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.2	—	Certification of the Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*32.1	—	Certification of the Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2	—	Certification of the Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*101	—	Interactive Data File

*	Filed herewith.

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this Quarterly Report on Form 10-Q to be signed on its behalf by the undersigned thereunto duly authorized.


				Hornbeck Offshore Services, Inc.

Date: August 9, 2011				/S/ JAMES O. HARP, JR.
				James O. Harp, Jr.
				Executive Vice President and Chief Financial Officer

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Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents