Helix Reports Second Quarter 2010 Results

 

HOUSTON, TX – Helix Energy Solutions Group, Inc. (NYSE: HLX) reported a net loss of $85.6 million, or $(0.82) per diluted share, for the second quarter of 2010 compared with net income of $100.2 million, or $0.94 per diluted share, for the same period in 2009, and a net loss of $17.9 million, or $(0.17) per diluted share, in the first quarter of 2010.  The net loss for the six months ended June 30, 2010 was $103.4 million, or $(1.00) per diluted share, compared with net income of $153.7 million, or $1.44 per diluted share, for the six months ended June 30, 2009.

 

 

Second quarter 2010 results included non-cash impairment charges of $159.9 million reflecting a reduction in carrying values of oil and gas properties following reductions of reserve estimates primarily associated with the reassessment of certain fields’ economics. The net impact of the impairments in the second quarter, after income taxes, was $1.00 per diluted share.

 

 

In addition, we recorded incremental depletion expense of $18.8 million in the second quarter of 2010 associated with the mid-year proved reserve reductions in our Bushwood field.

 

 

Owen Kratz, President and Chief Executive Officer of Helix, stated, “Aside from the impairment charges associated with our oil and gas properties, our second quarter results reflected a sharp sequential improvement in operating income reflecting improved market activity. Three of our vessels, the Q4000, the Express and the Helix Producer I (“HP I”) have been contracted by BP to participate in the coordinated response to the oil spill in the Gulf of Mexico. Ho wever, the operating results and utilization are fairly consistent with what we expected from these assets based on existing contracts with other customers. With the HP I on hire to BP, oil and gas production from the Phoenix field was deferred from its anticipated start up in the second quarter and we now expect Phoenix production to start up late in the third quarter. Strategically, we are continuing to actively pursue potential alternatives to exit the exploration and production business although the uncertainties brought about by the oil spill will likely have an impact on our efforts.”

 

 

 

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First quarter 2010 results included the following items on a pre-tax basis:

 

 

·	A $17.5 million settlement of litigation related to the termination of a 2007 international construction contract.

 

 

·	A net reduction of $5.2 million in the carrying values of certain oil and gas properties due primarily to the deterioration of field economics resulting from a decrease in natural gas prices.

 

 

The net impact of these items in the first quarter, after income taxes, was $0.14 per diluted share.

 

 

Second quarter 2009 results included the following items on a pre-tax basis:

 

·	A $59.4 million gain from sale of 24.2 million shares of Cal Dive common stock.

·	A $43.0 million net gain associated with insurance recoveries in connection with damage caused by Hurricane Ike in September 2008, which reflected net proceeds of $102.6 million, offset by hurricane-related expenses, impairments and additional asset retirement costs.

·	A reduction of $11.5 million in the carrying values of certain oil and gas properties due primarily to reserve revisions.

·	An $8.8 million gain from the sale of Helix RDS, our former reservoir consulting business.

 

The net impact of these items in the second quarter of 2009, after income taxes, was $0.63 per diluted share.

 

 

* * * * *

 

Summary of Results (1) (2)

 

 

(in thousands, except per share amounts and percentages, unaudited)

 

 

 

 

		Quarter Ended												Six Months Ended
		June 30								March 31				June 30
		2010				2009				2010				2010				2009
Revenues		$	299,262			$	494,639			$	201,570			$	500,832			$	1,065,614
Gross Profit (Loss):
Operating (3)		$	66,216			$	200,312			$	37,134			$	103,350			$	361,998
			22	%			40	%			18	%			21	%			34	%
Oil and Gas     Impairments (4)			(159,862	)			(63,073	)			(11,112	)			(170,974	)			(63,073	)
Exploration    Expense			(1,172	)			(1,483	)			(166	)			(1,338	)			(1,959	)
Total		$	(94,818	)		$	135,756			$	25,856			$	(68,962	)		$	296,966
Net Income (Loss) Applicable to Common Shareholders		$	(85,551	)		$	100,219			$	(17,891	)		$	(103,442	)		$	153,669
Diluted Earnings (Loss) Per Share		$	(0.82	)		$	0.94			$	(0.17	)		$	(1.00	)		$	1.44
Adjusted EBITDAX (5)		$	130,539			$	147,909			$	61,405			$	191,944			$	393,214

 

 

 

 

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Segment Information, Operational and Financial Highlights (1)

(in thousands, unaudited)

		Three Months Ended
		June 30,								March 31,
		2010				2009				2010
Revenues:
Contracting Services		$	202,317			$	239,476			$	154,200
Shelf Contracting (2)			-				197,656				-
Production Facilities			21,391				1,120				1,320
Oil and Gas			102,586				89,992				90,715
Intercompany Eliminations			(27,032	)			(33,605	)			(44,665	)
Total		$	299,262			$	494,639			$	201,570
Income (Loss) from Operations:
Contracting Services		$	43,781			$	34,636			$	27,486
Shelf Contracting (2)			-				38,145				-
Production Facilities			12,977				(1,018	)			(37	)
Oil and Gas (3)			3,609				103,380				10,614
Gain on Oil and Gas DerivativeCommodity Contracts			2,482				4,121				-
Oil and Gas Impairments (4)			(159,862	)			(63,073	)			(11,112	)
Exploration Expense			(1,172	)			(1,483	)			(166	)
Corporate (5)			(12,597	)			(11,253	)			(22,878	)
Intercompany Eliminations			(6,114	)			(1,631	)			(12,305	)
Total		$	(116,896	)		$	101,824			$	(8,398	)
Equity in Earnings of Equity Investments		$	1,656			$	6,264			$	5,055

 

Note: Footnotes listed at end of press release.

 

 

Contracting Services

 

o

Subsea Construction and Robotics revenues increased in the second quarter of 2010 compared to the first quarter of 2010 attributable to the Caesar being placed in service and an additional two vessels chartered by our Robotics division for ROV support operations. Overall our utilization rate for our owned and chartered vessels decreased to 74% in the second quarter of 2010 from 83% in the first quarter of 2010. Further, Robotics utilization was essentially flat in the second quarter of 2010 compared to the first quarter of 2010, 61% versus 59%. Finally, intercompany revenue eliminations associated with internal vessel utilization was significantly lower in the second quarter as compared to the first quarter of 2010 as we substantially completed our own oil and gas deve lopment projects.

 

o

Well Operations revenues in the second quarter of 2010 increased significantly due to near full utilization of our vessels. The Q4000 continues on hire with BP in response to the Macondo oil spill, while our North Sea vessels had nearly 100% utilization in the second quarter following the cessation of typical winter seasonality factors in the North Sea as well as out of service days in the first quarter of 2010 for the scheduled regulatory drydock of the Seawell.

 

 

 

 

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Production Facilities

 

o

The HP I, our dynamically positioned floating production unit, reached mechanical completion in early June 2010. Shortly thereafter, the HP I was contracted by BP to assist in the oil spill containment operations in the Gulf of Mexico. Once the HP I completes its contract with BP, the HP I will mobilize back to our Phoenix field and we expect to commence production late in the third quarter of 2010.

 

Oil and Gas

 

o	Oil and Gas revenues increased $11.9 million to $102.6 million in the second quarter of 2010 as production increased to 11.9 Bcfe in the second quarter of 2010 compared to 11.3 Bcfe in the first quarter of 2010.

 

o

The average prices realized for natural gas, including the effect of settled natural gas hedge contracts, totaled $6.10 per thousand cubic feet of gas (Mcf) in the second quarter of 2010 compared to $5.75 per Mcf in the first quarter of 2010. For oil, including the effects of settled hedge contracts, we realized $72.59 per barrel in the second quarter of 2010 compared to $71.82 per barrel in the first quarter of 2010.

 

o

We finalized our Gulf of Mexico (“GOM”) proved reserves estimate as of June 30, 2010 in conjunction with our regular mid-year review as well as our evaluation of our oil and gas assets in preparation for a potential divestment of the oil and gas business. GOM proved reserves of oil and natural gas totaled 400 Bcfe as compared with 543 Bcfe at December 31, 2009, adjusted for year to date 2010 production. The average prices used in our mid-year proved reserve estimates were $73.15 per barrel of oil and $4.07 per Mcf of natural gas as compared to $58.05 per barrel and $3.72 per Mcf at December 31, 2009. The present value of our total estimated GOM proved reserves using the SEC mandated PV-10 standardized measure was approximately $1.3 billion at both June 30, 2010 and December 31, 2009.

 

o	Our July oil and gas production rate averaged 110 million cubic feet of natural gas equivalent per day (MMcfe/d) through July 27, 2010 compared to an average of 131 MMcfe/d in the second quarter of 2010 and an average of 125 MMcfe/d in the first quarter of 2010.

 

o

At June 30, 2010, we have oil and gas hedge contracts in place for approximately 12 Bcf of natural gas and 1.7 million barrels of oil representing a substantial portion of our forecasted production for the remainder of 2010. We also have put oil and gas hedge contracts in place for 2011 totaling 7.2 Bcfe (450,000 barrels of oil and 4.5 Bcf of gas).

 

Other Expenses

 

o

Selling, general and administrative expenses were 8.2% of revenue in the second quarter of 2010, 11.4% in the first quarter of 2010 (excluding the $17.5 million pre-tax charge related to the settlement of litigation associated with the termination of a 2007 international construction contract), and 8.0% in the second quarter of 2009.

 

o

Net interest expense and other increased to $22.2 million in the second quarter of 2010 from $21.2 million in the first quarter of 2010. Net interest expense increased to $20.5 million in the second quarter of 2010 compared with $15.6 million in the first quarter of 2010. The increase in net interest expense resulted from a reduction of $4.6 million in capitalized interest from the first quarter of 2010 to the second quarter of 2010, which was attributable to the substantial completion of our capital projects. Also, we incurred foreign exchange losses related to declines in our non U.S. dollar functional currencies and currency contracts totaling $1.7 million in the second quarter of 2010 compared to $5.6 million in the first quarter of 2010.

 

Financial Condition and Liquidity

 

o

Consolidated net debt at June 30, 2010 decreased to $1.09 billion from $1.15 billion as of March 31, 2010. We had no borrowings under our revolver. Our total liquidity at June 30, 2010 was approximately $647 million, consisting of cash on hand of $270 million and revolver availability of $377 million. Net debt to book capitalization as of June 30, 2010 was 45%.  (Net debt to book capitalization is a non-GAAP measure.  See reconciliation attached hereto.)

 

 

 

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o	As of June 30, 2010, we were in compliance with our covenants under our various loan agreements.

 

o	We incurred capital expenditures (including capitalized interest) totaling $37 million in the second quarter of 2010, compared to $75 million in the first quarter of 2010 and $57 million in the second quarter of 2009 (excluding amounts related to Cal Dive in second quarter 2009).

 

 

Footnotes to “Summary of Results”:

 

(1)	Results of Helix RDS Limited, our former reservoir consulting business, included as discontinued operations for all periods presented in our comparative condensed consolidated statements of operations.

(2)

Results of Cal Dive, our former Shelf Contracting business, were consolidated through June 10, 2009, at which time our ownership interest dropped below 50%. Our remaining interest was accounted for under the equity method of accounting through September 23, 2009. Subsequent to September 23, 2009 our investment in Cal Dive was accounted for as an available for sale security.

(3)	Included insurance recoveries of $102.6 million offset by hurricane-related costs of $8.1 million in the second quarter of 2009.

(4)

Second quarter 2010 oil and gas impairments of $159.9 million related to reduction of the carrying values of certain oil and gas properties due to reserve revisions. First quarter 2010 impairments on our U.S. oil and gas properties ($7.0 million) were due primarily to the deterioration of certain fields’ economics following a significant decrease in natural gas prices during the period. We also impaired our U.K. offshore property ($4.1 million) during the first quarter. The U.K. impairment was offset by a gain on the reacquisition of our 50% partner’s interest in the U.K. field. Second quarter 2009 oil and gas impairments included $51.5 million of additional asset retirement and impairment costs resulting from Hurricane Ike, and $11.5 million in the reduction of the carrying values of certain oil and gas properties due to reserve revisions.

(5)	Non-GAAP measure.  See reconciliation attached hereto.

 

Footnotes to “Segment Information, Operational and Financial Highlights”:

 

(1)	Results of Helix RDS Limited, our former reservoir consulting business, were included as discontinued operations for all periods presented in our comparative condensed consolidated statements of operations.

(2)

Results of Cal Dive, our former Shelf Contracting business, were consolidated through June 10, 2009, at which time our ownership interest dropped below 50%. Our remaining interest was accounted for under the equity method of accounting through September 23, 2009. Subsequent to September 23, 2009 our investment in Cal Dive was accounted for as an available for sale security.

(3)	Included insurance recoveries of $97.7 million offset by hurricane-related costs of $7.4 million in the second quarter of 2009.

(4)

Second quarter 2010 oil and gas impairments of $159.9 million related to reduction of the carrying values of certain oil and gas properties due to reserve revisions. First quarter 2010 impairments on our U.S. oil and gas properties ($7.0 million) were due primarily to the deterioration of certain fields’ economics following a significant decrease in natural gas prices during the period. We also impaired our U.K. offshore property ($4.1 million) during the first quarter. The U.K. impairment was offset by a gain on the reacquisition of our 50% partner’s interest in the U.K. field. Second quarter 2009 oil and gas impairments included $51.5 million of additional asset retirement and impairment costs resulting from Hurricane Ike, and $11.5 million in the reduction of the carrying values of certain oil and gas properties due to reserve revisions.

(5)	First quarter of 2010 included litigation settlement related to the termination of a 2007 international construction contract.

 

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Further details are provided in the presentation for Helix’s quarterly conference call to review its second quarter 2010 results (see the “Investor Relations” page of Helix’s website, www.HelixESG.com).  The call, scheduled for 9:00 a.m. Central Daylight Time on Thursday, July 29, 2010, will be audio webcast live from the “Investor Relations” page of Helix’s website. Investors and other interested parties wishing to listen to the call via telephone may join the call by dialing 800 741 5804 (Domestic) or 1 212 231 2907 (International).  The pass code is Tripodo.  A replay wil l be available from the Audio Archives page on Helix’s website until October 28, 2010.

 

 

Helix Energy Solutions Group, headquartered in Houston, Texas, is an international offshore energy company that provides development solutions and other key life of field services to the open energy market as well as to our own oil and gas business unit.  That business unit is a prospect generation, exploration, development and production company.  Employing our own key services and methodologies, we seek to lower finding and development costs, relative to industry norms.

 

 

 

 

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Management evaluates Company performance and financial condition using certain non-GAAP metrics, primarily Adjusted EBITDAX, net debt and net debt to book capitalization.  We calculate Adjusted EBITDAX as earnings before net interest expense, taxes, depreciation and amortization and exploration expense.  Further, we do not include earnings from our interest in Cal Dive in any periods presented in our Adjusted EBITDAX calculation.  Net debt is calculated as the sum of financial debt less cash and equivalents on hand.  Net debt to book capitalization is calculated by dividing net debt by the sum of net debt, convertible preferred stock and shareholders’ equity.  These non-GAAP measures are useful to investors and other internal and external users of our financial statements in evaluating our operating performance because they are widely used by investors in our industry to measure a company’s operating performance without regard to items which can vary substantially from company to company, and help investors meaningfully compare our results from period to period.  Adjusted EBITDAX should not be considered in isolation or as a substitute for, but instead is supplemental to, income from operations, net income or other income data prepared in accordance with GAAP.  Non-GAAP financial measures should be viewed in addition to, and not as an alternative to our reported results prepared in accordance with GAAP.  Users of this financial information should consider the types of events and transactions which are excluded.

 

 

This press release contains forward-looking statements that involve risks, uncertainties and assumptions that could cause our results to differ materially from those expressed or implied by such forward-looking statements.  All statements, other than statements of historical fact, are "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995, including, without limitation, any projections of financial items; future production volumes, results of exploration, exploitation, development, acquisition and operations expenditures, and prospective reserve levels of property or wells; any statements of the plans, strategies and objectives of management for future operations; any statement concerning developments, performance or industry rankings; any statements regarding future economic conditions or performance; any statements of expectation or belief; and any statements of assumptions underlying any of the foregoing.  The forward looking statements are subject to a number of known and unknown risks, uncertainties and other factors including the performance of contracts by suppliers, customers and partners; employee management issues; uncertainties inherent in the exploration for and development of oil and gas and in estimating reserves; complexities of global political and economic developments; geologic risks, volatility of oil and gas prices and other risks described from time to time in our reports filed with the Securities and Exchange Commission ("SEC"), including the company's Annual Report on Form 10-K for the year ending December 31, 2009 and any subsequent Quarterly Report on Form 10-Q.  We assume no obligation and do not intend to update these forward-looking statements except as required by the securities laws.

 

 

 

 

 

 

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HELIX ENERGY SOLUTIONS GROUP, INC.
Comparative Condensed Consolidated Statements of Operations
							Three Months Ended Jun. 30,				Six Months Ended Jun. 30,
	(in thousands, except per share data)						2010		2009		2010		2009
							(unaudited)				(unaudited)
	Net revenues:
		Contracting services					$      196,676		$      404,647		$      307,531		$       815,441
		Oil and gas					102,586		89,992		193,301		250,173
							299,262		494,639		500,832		1,065,614
	Cost of sales:
		Contracting services					140,126		312,502		226,374		638,200
		Oil and gas					94,092		(16,692)		172,446		67,375
		Oil and gas impairments					159,862		63,073		170,974		63,073
							394,080		358,883		569,794		768,648
	Gross profit (loss)						(94,818)		135,756		(68,962)		296,966
		Gain on oil and gas derivative commodity contracts					2,482		4,121		2,482		78,730
		Gain (loss) on sale of assets, net					(14)		1,319		6,233		1,773
		Selling and administrative expenses					(24,546)		(39,372)		(65,047)		(80,725)
	Income (loss) from operations						(116,896)		101,824		(125,294)		296,744
		Equity in earnings of investments					1,656		6,264		6,711		13,767
		Gain on subsidiary equity transaction					-		59,442		-		59,442
		Net interest expense and other					(22,182)		(7,468)		(43,375)		(29,663)
	Income (loss) before income taxes						(137,422)		160,062		(161,958)		340,290
		Provision (benefit) for income taxes					(52,366)		56,809		(59,927)		121,728
	Income (loss) from continuing operations						(85,056)		103,253		(102,031)		218,562
		Discontinued operations, net of tax					(17)		9,836		(44)		7,282
	Net income (loss), including noncontrolling interests						(85,073)		113,089		(102,075)		225,844
		Less: net income applicable to noncontrolling interests					(444)		(12,620)		(1,273)		(18,173)
	Net income (loss) applicable to Helix						(85,517)		100,469		(103,348)		207,671
		Preferred stock dividends					(34)		(250)		(94)		(563)
		Preferred stock beneficial conversion charges					-		-		-		(53,439)
	Net income (loss) applicable to Helix common shareholders						$       (85,551)		$      100,219		$     (103,442)		$       153,669
	Weighted Avg. Common Shares Outstanding:
		Basic					104,125		96,936		103,610		96,077
		Diluted					104,125		105,995		103,610		106,000
	Basic earnings (loss) per share of common stock:
		Continuing operations					($0.82)		$0.92		($1.00)		$1.50
		Discontinued operations					$0.00		$0.10		$0.00		$0.08
		Net income (loss) per share of common stock					($0.82)		$1.02		($1.00)		$1.58
	Diluted earnings (loss) per share of common stock:
		Continuing operations					($0.82)		$0.85		($1.00)		$1.37
		Discontinued operations					$0.00		$0.09		$0.00		$0.07
		Net income (loss) per share of common stock					($0.82)		$0.94		($1.00)		$1.44
Comparative Condensed Consolidated Balance Sheets
ASSETS							LIABILITIES & SHAREHOLDERS' EQUITY
(in thousands)				Jun. 30, 2010		Dec. 31, 2009	(in thousands)				Jun. 30, 2010		Dec. 31, 2009
				(unaudited)							(unaudited)
Current Assets:							Current Liabilities:
	Cash and equivalents			$       270,001		$        270,673	Accounts payable				$      163,975		$       155,457
	Accounts receivable			204,377		172,678	Accrued liabilities				202,154		200,607
	Other current assets			120,670		122,209	Current mat of L-T debt (1)				11,396		12,424
Total Current Assets				595,048		565,560	Total Current Liabilities				377,525		368,488
Net Property & Equipment:							Long-term debt (1) (2)				1,347,994		1,348,315
	Contracting Services			1,482,576		1,470,582	Deferred income taxes				383,652		442,607
	Oil and Gas			1,182,984		1,393,124	Asset retirement obligations				165,799		182,399
Equity investments				187,694		189,411	Other long-term liabilities				5,109		4,262
Goodwill				76,134		78,643	Convertible preferred stock (1)				1,000		6,000
Other assets, net				82,137		82,213	Shareholders' equity (1)				1,325,494		1,427,462
Total Assets				$     3,606,573		$     3,779,533	Total Liabilities & Equity				$   3,606,573		$    3,779,533
(1)	Net debt to book capitalization - 45% at June 30, 2010. Calculated as total debt less cash and equivalents ($1,089,389)
	divided by sum of total net debt, convertible preferred stock and shareholders' equity ($2,415,883).
(2)	Reflects impact of retrospective adoption of accounting standard which required bifurcation of Helix's convertible senior notes
	between debt and equity components.  Impact on June 30, 2010 and December 31, 2009 was a reduction in debt totaling
	$22.8 million and $26.9 million, respectively.

 

 

 

 

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Helix Energy Solutions Group, Inc.
Reconciliation of Non GAAP Measures
Three and Six Months Ended June 30, 2010
Earnings Release:
Reconciliation From Net Income to Adjusted EBITDAX:
				2Q10	2Q09	1Q10	2010	2009
				(in thousands)
Net income (loss) applicable to common shareholders				$       (85,551)	$      100,219	$       (17,891)	$     (103,442)	$      153,669
Non-cash impairment				159,862	19,261	11,112	170,974	19,261
(Gain) loss on asset sales				41	(69,569)	(6,247)	(6,206)	(70,023)
Preferred stock dividends				34	250	60	94	54,002
Income tax provision (benefit)				(52,366)	50,072	(7,563)	(59,929)	114,866
Net interest expense and other				22,144	5,776	21,179	43,323	26,369
Depreciation and amortization				85,203	68,221	60,589	145,792	142,198
Exploration expense				1,172	1,483	166	1,338	1,959
Adjusted EBITDAX (including Cal Dive)				$      130,539	$      175,713	$        61,405	$      191,944	$      442,301
Less: Previously reported contribution from Cal Dive				$              -	$       (27,804)	$              -	$              -	$       (49,087)
Adjusted EBITDAX				$      130,539	$      147,909	$        61,405	$      191,944	$      393,214
	We calculate adjusted EBITDAX as earnings before net interest expense, taxes, depreciation and amortization, and exploration
	expense. Further, we do not include earnings from our interest in Cal Dive in any periods presented in our adjusted EBITDAX calculation.
	These non-GAAP measures are useful to investors and other internal and external users of our financial statements in evaluating
	our operating performance because they are widely used by investors in our industry to measure a company's operating performance
	without regard to items which can vary substantially from company to company and help investors meaningfully
	compare our results from period to period.  Adjusted EBITDAX should not be considered in isolation or as a substitute
	for, but instead is supplemental to,  income from operations, net income or other income data prepared in
	accordance with GAAP.  Non-GAAP financial measures should be viewed in addition to, and not as an alternative
	to our reported results prepared in accordance with GAAP.  Users of this financial information should consider
	the types of events and transactions which are excluded.

 

 

 

Helix Energy Solutions Group, Inc.
Reconciliation of Non GAAP Measures
Three Months Ended June 30, 2010
Earnings Release:
Reconciliation of unusual items:
				2Q10		2Q09		1Q10
				(in thousands, except per share data)
Non-cash property impairments and other charges:
	Property impairments			$         159,862		$           11,524		$           11,112
	Settlement of litigation			-		-		17,455
	Gain on acquisition or asset sales			-		(68,250)		(5,960)
	Insurance gains			-		(42,969)		-
	Tax (benefit) provision associated with above			(55,952)		32,265		(7,860)
Non-cash property impairments and other charges, net:				$         103,910		$          (67,430)		$           14,747
Diluted shares				104,125		105,995		103,090
Net after income tax effect per share				$              1.00		$             (0.63)		$              0.14

 

 

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July 29, 2010

Second Quarter 2010 Conference Call

Helix Producer I operating at BP Macondo spill site

 

 

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Changing the way you succeed.

Forward-Looking Statements

2

This presentation contains forward-looking statements within the meaning of Section 27A of the Securities Act of
1933 and Section 21E of the Securities Exchange Act of 1934. All such statements, other than statements of
historical fact, are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of
1995, including, without limitation, any projections of financial items; future production volumes, results of
exploration, exploitation, development, acquisition and operations expenditures, and prospective reserve levels of
properties or wells; any statements of the plans, strategies and objectives of management for future operations; any
statements concerning developments, performance or industry rankings; and any statements of assumptions
underlying any of the foregoing. These statements involve certain assumptions we made based on our experience
and perception of historical trends, current conditions, expected future developments and other factors we believe
are reasonable and appropriate under the circumstances. The forward-looking statements are subject to a number
of known and unknown risks, uncertainties and other factors that could cause our actual results to differ materially.
The risks, uncertainties and assumptions referred to above include the performance of contracts by suppliers,
customers and partners; employee management issues; local, national and worldwide economic conditions;
uncertainties inherent in the exploration for and development of oil and gas and in estimating reserves; complexities
of global political and economic developments; geologic risks, volatility of oil and gas prices and other risks described
from time to time in our reports filed with the Securities and Exchange Commission (“SEC”), including the Company’s
Annual Report on Form 10-K for the year ended December 31, 2009, and any subsequent quarterly report on Form
10-Q. You should not place undue reliance on these forward-looking statements which speak only as of the date of
this presentation and the associated press release. We assume no obligation or duty and do not intend to update
these forward-looking statements except as required by the securities laws.

References to quantities of oil or gas include amounts we believe will ultimately be produced, and may include
“proved reserves” and quantities of oil or gas that are not yet classified as “proved reserves” under SEC definitions.
Statements of oil and gas reserves are estimates based on assumptions and may be imprecise. Investors are urged
to consider closely the disclosure regarding reserves in our 2009 Form 10-K.

 

 

 

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Changing the way you succeed.

Presentation Outline

3

• Executive Summary

 Summary of Q2 2010 Results (pg. 4)

 2010 Outlook (pg. 8)

• Operational Highlights by Segment

 Contracting Services (pg. 11)

 Oil & Gas (pg. 17)

• Key Balance Sheet Metrics (pg. 20)

• Non-GAAP Reconciliations (pg. 22)

• Questions & Answers

Q4000 flaring oil and gas at BP Macondo spill site

 

 

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Changing the way you succeed.

Executive Summary

4

($ in millions, except per share data)

(A) Results of Cal Dive, our former Shelf Contracting business, were consolidated through June 10, 2009, at which time our ownership interest dropped below 50%; thereafter, our remaining
 interest was accounted for under the equity method of accounting until September 23, 2009, when we reduced our holdings with the sale of a substantial portion of our remaining interest in
 Cal Dive. Revenues from our Shelf Contracting business totaled $197.7 million and $404.7 million in the three and six months ended June 30, 2009.

(B) Included revenues of $73.5 million of previously disputed accrued royalties in first quarter 2009.

(C) After $53.4 million of non-cash charges related to convertible preferred stock in first quarter 2009.

(D) See non-GAAP reconciliations on slides 22-23.

(E) EBITDAX excludes Cal Dive contribution in all periods presented.

(B)

(C)

(A)

 

 

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Changing the way you succeed.

Executive Summary

5

 Second quarter results included the following matters:

 • Non-cash impairment charges of $159.9 million ($1.00 per diluted share, after taxes) primarily
 associated with a reduction in carrying values of 15 Gulf of Mexico (“GOM”) shelf oil and gas
 properties due to a revision in mid-year proved reserve estimates resulting from the
 reassessment of field economics.

 • In addition, we recorded incremental depletion expense of $18.8 million as a result of a reduction
 in mid-year proved reserves for our deepwater Bushwood field.

 

 

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Changing the way you succeed.

Executive Summary

6

• Contracting Services

 o High utilization of Well Ops vessels; Well Enhancer and Seawell in the North Sea and Q 4000 in
 the Gulf of Mexico

 o Helix Producer I placed into service and contracted to BP

 o Caesar placed into service and commenced GOM pipeline installation

• Oil and Gas

 o Mid-year GOM reserve report finalized, with proved reserves of approximately 400 Bcfe

 o Estimated PV-10 value of approximately $1.3 billion

 o Downward revision of approximately 140 Bcfe from year end

 o Proved developed- 43%

 o Proved undeveloped- 57%

 o Oil- 40%, Gas- 60%

 o Second quarter average production rate of approximately 131 Mmcfe/d

 o July average production rate of approximately 110 Mmcfe/d through the 27th

 o Phoenix production to start upon return of Helix Producer I from BP spill containment operations

 

 

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Changing the way you succeed.

Executive Summary

7

• Oil and gas production totaled 11.9 Bcfe for Q2 2010 versus 11.3 Bcfe in Q1 2010

 o Avg realized price for oil of $72.59 / bbl ($71.82 / bbl in Q1 2010), inclusive of hedges

 o Avg realized price for gas of $6.10 / Mcf ($5.75 / Mcf in Q1 2010), inclusive of hedges

• Balance sheet remains strong (see slide 20)

 o Net debt balance of $1.09 billion at June 30, 2010

 o Liquidity* of $647 million at June 30, 2010

*Liquidity as we define it is equal to cash and cash equivalents ($270 million), plus available capacity under our revolving credit facility ($377 million).

Oil and Gas (continued)

 

 

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Changing the way you succeed.

2010 Outlook

8

• Contracting Services activity in Q3 2010 expected to stay consistent with Q2

 o Q4 activity forecasted to decline due to seasonal and other factors

 o Well intervention activity particularly robust

• Oil and gas revised downward

 o Deferred start-up of Phoenix production due to HPI / BP operations

 o Higher DD&A rates due to Bushwood reserve revisions; DD&A rates comparable to
 Q2, 2010

• Capital expenditures of approximately $190 million expected for 2010

 o $80 million relates to completion of major vessel projects

 o Oil and Gas capital expenditures of approximately $70 million, excluding P&A of
 approximately $60 million

 

 

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Changing the way you succeed.

2010 Outlook

9

Broad Metrics	2010 Higher End	2010 Lower End	2009
Production Range	45 Bcfe	40 Bcfe	44 Bcfe
EBITDA	$450 million	$400 million	$490 million
CAPEX	$190 million	$190 million	$328 million

Commodity Price Deck		2010 Higher End	2010 Lower End	2009
Hedged	Oil	$75.43/ bbl	$75.51 / bbl	$67.11 / bbl
	Gas	$5.82 / mcf	$5.94 / mcf	$7.75 / mcf

 

 

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Changing the way you succeed.

10

Operations Highlights

 

 

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Changing the way you succeed.

11

($ in millions, except percentages)

(A) Results of Cal Dive, our former
 Shelf Contracting business, were
 consolidated through June 10,
 2009, at which time our ownership
 interest dropped below 50%;
 thereafter, our remaining interest
 was accounted for under the equity
 method of accounting until
 September 23, 2009, when we
 reduced our holdings with the sale
 of a substantial portion of our
 remaining interest in Cal Dive.

(B) See non-GAAP reconciliation on
 slides 22-23. Amounts are prior to
 intercompany eliminations.

(C) Includes both charter fee to Phoenix
 field and BP.

(D) Amounts primarily represent equity
 in earnings of Marco Polo and
 Independence Hub investments, net
 of our share of losses ($4.3 million
 and $1.4 million in the second
 quarter and first quarter of 2010,
 respectively) associated with the
 startup of the CloughHelix JV in
 Australia.

Contracting Services

 

 

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Contracting Services Q2 2010 Utilization

Intrepid
Express
Caesar (placed in service end of May)

Olympic Canyon

Olympic Triton

Island Pioneer

Seawell
Well Enhancer
Q4000

40 ROVs

2 ROV Drill Units

5 Trenchers

Deep Cygnus
Normand Fortress

12

 

 

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13

Macondo Containment (MC252)

Helix Containment Vessels

 

 

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Changing the way you succeed.

14

Q4000 as command vessel for top kill operations

Q4000 burning oil & gas

New buoy for HPI under construction

HPI in MC252 processing Macondo production

Helix vessels at work in MC252

Helix is well positioned to support GOM Producers

 

 

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Changing the way you succeed.

15

Contracting Services - Subsea Construction

Subsea Construction

• Caesar commenced installation
 of 46 mile / 20 inch pipeline in
 GOM

• Express and Intrepid enjoyed
 high utilization in the quarter

• Expect third quarter utilization
 for subsea construction fleet to
 be >90%

ROV - Robotics

• Enjoyed high utilization for five chartered ROV support
 vessels. Seacor Canyon has been returned to owners

• Island Pioneer and Deep Cygnus with Canyon trenchers
 T750 and I-Trencher active in North Sea and offshore
 Norway

• Olympic Triton worked for Technip on the Jubilee project
 offshore Ghana

• All ROV support vessels operated outside of the GOM in Q2

 Canyon ROV working on Jubilee project offshore Ghana

 

 

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Changing the way you succeed.

16

Contracting Services - Well Ops

North America

• Q4000 worked for Newfield on deepwater well
 intervention job in April and on BP Macondo
 containment, top kill and burn-off in May and June

• Healthy backlog for remainder of 2010

North Sea

• Seawell and Well Enhancer enjoyed 99% utilization in
 the quarter with strong performance on well intervention
 projects in the North Sea

• Progressing Statoil Cat B FEED study for new well
 intervention semi-submersible for offshore Norway

• Healthy backlog for remainder of 2010

Asia Pacific

• Executed contract with China National Offshore Oil
 Company (CNOOC) for Lufeng well intervention project
 in South China Sea using the Normand Clough

• Work commenced in Q3, 2010

Well Ops APAC Subsea Intervention Lubricator being
tested for Well Ops Lufeng project

 

 

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Changing the way you succeed.

17

(A) Reflects hurricane insurance
 proceeds less related costs. In
 Q2 2009 proceeds totaled $97.7
 million, offset by $7.4 million of
 hurricane-related repair costs
 and $51.5 million of additional
 hurricane-related impairment
 charges, including an estimated
 $43.8 million increase to our
 asset retirement obligations for
 hurricane-affected properties.

(B) Second quarter 2010
 impairments primarily associated
 with the reduction in carrying
 values of 15 GOM properties due
 to a revision in mid-year
 reserves. Second quarter 2009
 impairments related to reduction
 in carrying values of certain oil
 and gas properties due to
 reserve revisions. First quarter
 2010 impairments related to
 deterioration in certain field
 economics due to lower natural
 gas prices in the period.

(C) Including effect of settled hedges
 and mark-to-market derivative
 contracts.

Oil & Gas

 

 

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Changing the way you succeed.

Oil & Gas

18

(A) Included accretion expense and an incremental $18.8 million in the quarter ended June 30, 2010 for our Bushwood field.

(B) Excluded hurricane-related repairs of $1.6, $(90.3) and $2.1 million, net of insurance recoveries, for the quarters ended June 30, 2010, June 30, 2009 and
 March 31, 2010, respectively.

(C) Excluded exploration expenses of $1.2, $1.5 and $0.2 million, and abandonment costs of $0.4, $0.8 and $0.8 million for the quarters ended June 30, 2010,
 June 30, 2009 and March 31, 2010, respectively.

Operating Costs ($ in millions, except per Mcfe data)

 

 

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Summary of July 2010 - Dec 2011 Hedging Positions

19

 

 

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Changing the way you succeed.

Key Balance Sheet Metrics

20

Debt (A)

 Liquidity (B) of $647 million at 6/30/10

 

 (A) Includes impact of unamortized debt discount under our Convertible Senior Notes.

 (B) Liquidity as we define it is equal to cash and cash equivalents ($270 million), plus
 available capacity under our revolving credit facility ($377 million).

 

 

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Changing the way you succeed.

21

Non-GAAP
Reconciliations

 

 

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Changing the way you succeed.

Non GAAP Reconciliations

22

Adjusted EBITDAX ($ in millions)

We calculate adjusted EBITDAX as earnings before net interest expense, taxes, depreciation and amortization,   

and exploration expense. Further, we do not include earnings from our former interest in Cal Dive in any periods presented in our adjusted
EBITDAX calculation. These non-GAAP measures are useful to investors and other internal and external users of our financial statements in
evaluating our operating performance because they are widely used by investors in our industry to measure a company's operating 

performance without regard to items which can vary substantially from company to company and help investors meaningfully compare our results
from period to period. Adjusted EBITDAX should not be considered in isolation or as a substitute for, but instead is supplemental to, income from
operations, net income or other income data prepared in accordance with GAAP. Non-GAAP financial measures should be viewed in addition to,
and not as an alternative to our reported results prepared in accordance with GAAP. Users of this financial information should consider the types
of events and transactions which are excluded.     
  

 

 

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Revenue and Gross Profit As Reported ($ in millions)

23

Non GAAP Reconciliations

 

 

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