Document And Entity Information (USD $) In Billions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Feb. 13, 2015	Jun. 30, 2014
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2014
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2014
Entity Registrant Name	HELIX ENERGY SOLUTIONS GROUP INC
Entity Central Index Key	0000866829
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		105,906,969
Entity Current Reporting Status	Yes
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Public Float			$ 2.6

Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$ 476,492	$ 478,200
Accounts receivable:
Trade, net of allowance for uncollectible accounts of $4,735 and $2,234, respectively	104,724	156,925
Unbilled revenue	28,542	25,732
Costs in excess of billing	2,034	1,508
Current deferred tax assets	31,180	51,573
Other current assets	51,301	29,709
Total current assets	694,273	743,647
Property and equipment	2,241,444	1,963,706
Less accumulated depreciation	(506,060)	(431,489)
Property and equipment, net	1,735,384	1,532,217
Other assets:
Equity investments	149,623	157,919
Goodwill	62,146	63,230
Other assets, net	59,272	47,267
Total assets	2,700,698	2,544,280
Current liabilities:
Accounts payable	83,403	72,602
Accrued liabilities	104,923	96,482
Income tax payable	9,143	760
Current maturities of long-term debt	28,144	20,376
Total current liabilities	225,613	190,220
Long-term debt	523,228	545,776
Deferred tax liabilities	260,275	265,879
Other non-current liabilities	38,108	18,295
Total liabilities	1,047,224	1,020,170
Commitments and contingencies
Shareholders' equity:
Common stock, no par, 240,000 shares authorized, 105,586 and 105,640 shares issued, respectively	934,447	933,507
Retained earnings	781,279	586,232
Accumulated other comprehensive loss	(62,252)	(20,688)
Total controlling interest shareholders' equity	1,653,474	1,499,051
Noncontrolling interests		25,059
Total equity	1,653,474	1,524,110
Total liabilities and shareholders' equity	$ 2,700,698	$ 2,544,280

Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Current assets:
Allowance for uncollectible accounts	$ 4,735	$ 2,234
Shareholders' equity:
Common stock, par value
Common stock, shares authorized	240,000,000	240,000,000
Common stock, shares issued	105,586,000	105,640,000

Consolidated Statements Of Operations (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Consolidated Statements Of Operations [Abstract]
Net revenues	$ 1,107,156	$ 876,561	$ 846,109
Cost of sales:
Cost of sales	763,120	615,876	619,059
Asset impairment charges			177,135
Total cost of sales	763,120	615,876	796,194
Gross profit	344,036	260,685	49,915
Loss on commodity derivative contracts		(14,113)	(10,507)
Gain (loss) on disposition of assets, net	10,240	14,727	(13,476)
Selling, general and administrative expenses	(92,520)	(82,265)	(94,415)
Income (loss) from operations	261,756	179,034	(68,483)
Equity in earnings of investments	879	2,965	8,434
Net interest expense	(17,859)	(32,898)	(48,160)
Loss on early extinguishment of long-term debt		(12,100)	(17,127)
Other income (expense), net	814	6	(662)
Other income - oil and gas	16,931	6,581
Income (loss) before income taxes	262,521	143,588	(125,998)
Income tax provision (benefit)	66,971	31,612	(59,158)
Net income (loss) from continuing operations	195,550	111,976	(66,840)
Income from discontinued operations, net of tax		1,073	23,684
Net income (loss), including noncontrolling interests	195,550	113,049	(43,156)
Less net income applicable to noncontrolling interests	(503)	(3,127)	(3,178)
Net income (loss) applicable to Helix	$ 195,047	$ 109,922	$ (46,334)
Basic earnings (loss) per share of common stock:
Continuing operations	$ 1.85	$ 1.03	$ (0.67)
Discontinued operations		$ 0.01	$ 0.23
Net income (loss) per common share	$ 1.85	$ 1.04	$ (0.44)
Diluted earnings (loss) per share of common stock:
Continuing operations	$ 1.85	$ 1.03	$ (0.67)
Discontinued operations		$ 0.01	$ 0.23
Net income (loss) per common share	$ 1.85	$ 1.04	$ (0.44)
Weighted average common shares outstanding:
Basic	105,029	105,032	104,449
Diluted	105,045	105,184	104,449

Consolidated Statements Of Comprehensive Income (Loss) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Consolidated Statements Of Comprehensive Income (Loss) [Abstract]
Net income (loss), including noncontrolling interests	$ 195,550	$ 113,049	$ (43,156)
Other comprehensive loss, net of tax:
Unrealized loss on hedges arising during the period	(37,364)	(16,847)	(22,773)
Reclassification adjustments for loss included in net income	3,365	1,476	(2,661)
Reclassification adjustments for loss from derivatives de-designated as cash flow hedges included in net income			5,524
Income taxes on unrealized loss on hedges	11,899	5,380	6,969
Unrealized loss on hedges, net of tax	(22,100)	(9,991)	(12,941)
Foreign currency translation gain (loss)	(19,464)	4,970	7,291
Other comprehensive loss, net of tax	(41,564)	(5,021)	(5,650)
Comprehensive income (loss)	153,986	108,028	(48,806)
Less comprehensive income applicable to noncontrolling interests	(503)	(3,127)	(3,178)
Comprehensive income (loss) applicable to Helix	$ 153,483	$ 104,901	$ (51,984)

Consolidated Statements Of Shareholders' Equity (USD $) In Thousands	Common Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Parent [Member]	Noncontrolling Interest [Member]	Total
Balance at Dec. 31, 2011	$ 908,776	$ 522,644	$ (10,017)	$ 1,421,403	$ 28,138	$ 1,449,541
Balance, shares at Dec. 31, 2011	105,530
Net income (loss)		(46,334)		(46,334)	3,178	(43,156)
Foreign currency translation adjustments			7,291	7,291		7,291
Unrealized loss on hedges, net			(12,941)	(12,941)		(12,941)
Distributions to noncontrolling interests					(5,287)	(5,287)
Equity component of debt discount on Convertible Senior Notes due 2032	22,419			22,419		22,419
Convertible preferred stock conversion, value	1,000			1,000		1,000
Convertible preferred stock conversion, shares	362
Stock compensation expense	7,361			7,361		7,361
Stock repurchases, value	(6,415)			(6,415)		(6,415)
Stock repurchases, shares	(405)
Activity in company stock plans, net and other, value	787			787		787
Activity in company stock plans, net and other, shares	276
Excess tax from stock-based compensation	(1,186)			(1,186)		(1,186)
Balance at Dec. 31, 2012	932,742	476,310	(15,667)	1,393,385	26,029	1,419,414
Balance, shares at Dec. 31, 2012	105,763
Net income (loss)		109,922		109,922	3,127	113,049
Foreign currency translation adjustments			4,970	4,970		4,970
Unrealized loss on hedges, net			(9,991)	(9,991)		(9,991)
Distributions to noncontrolling interests					(4,097)	(4,097)
Equity component of debt discount on Convertible Senior Notes due 2032	49			49		49
Stock compensation expense	7,510			7,510		7,510
Stock repurchases, value	(8,855)			(8,855)		(8,855)
Stock repurchases, shares	(390)
Activity in company stock plans, net and other, value	1,842			1,842		1,842
Activity in company stock plans, net and other, shares	267
Excess tax from stock-based compensation	219			219		219
Balance at Dec. 31, 2013	933,507	586,232	(20,688)	1,499,051	25,059	1,524,110
Balance, shares at Dec. 31, 2013	105,640
Net income (loss)		195,047		195,047	503	195,550
Foreign currency translation adjustments			(19,464)	(19,464)		(19,464)
Unrealized loss on hedges, net			(22,100)	(22,100)		(22,100)
Distributions to noncontrolling interests					(1,018)	(1,018)
Acquisition of noncontrolling interests	2,898			2,898	(24,544)	(21,646)
Stock compensation expense	2,176			2,176		2,176
Stock repurchases, value	(7,698)			(7,698)		(7,698)
Stock repurchases, shares	(321)
Activity in company stock plans, net and other, value	3,496			3,496		3,496
Activity in company stock plans, net and other, shares	267
Excess tax from stock-based compensation	68			68		68
Balance at Dec. 31, 2014	$ 934,447	$ 781,279	$ (62,252)	$ 1,653,474		$ 1,653,474
Balance, shares at Dec. 31, 2014	105,586

Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities:
Net income (loss), including noncontrolling interests	$ 195,550	$ 113,049	$ (43,156)
Adjustments to reconcile net income (loss), including noncontrolling interests, to net cash provided by operating activities:
Income from discontinued operations, net of tax		(1,073)	(23,684)
Depreciation and amortization	109,345	98,535	97,201
Asset impairment charges			177,135
Amortization of deferred financing costs	4,870	5,187	9,086
Stock-based compensation expense	3,133	8,307	7,627
Amortization of debt discount	5,596	5,172	9,729
Deferred income taxes	23,154	(24,937)	(69,584)
Excess tax from stock-based compensation	(68)	(219)	1,186
(Gain) loss on disposition of assets, net	(10,240)	(14,727)	13,476
Loss on early extinguishment of debt		12,100	17,127
Unrealized (gain) loss and ineffectiveness on derivative contracts, net	1,320	77	(250)
Changes in operating assets and liabilities:
Accounts receivable, net	43,963	(3,320)	(3,652)
Other current assets	(6,461)	14,277	(10,434)
Income tax payable	9,088	(56,164)	(16,812)
Accounts payable and accrued liabilities	12,841	(32,045)	73,448
Oil and gas asset retirement costs	(1,024)	(10,334)	(37,970)
Other noncurrent, net	(31,582)	(9,024)	(24,405)
Net cash provided by operating activities	359,485	104,861	176,068
Net cash provided by (used in) discontinued operations		(30,503)	276,430
Net cash provided by operating activities	359,485	74,358	452,498
Cash flows from investing activities:
Capital expenditures	(336,912)	(324,426)	(323,039)
Distributions from equity investments, net	7,911	9,295	7,797
Proceeds from sale of assets	13,574	189,054	19,530
Acquisition of noncontrolling interests	(20,085)
Net cash used in investing activities	(335,512)	(126,077)	(295,712)
Net cash provided by (used in) discontinued operations		582,965	(120,057)
Net cash provided by (used in) investing activities	(335,512)	456,888	(415,769)
Cash flows from financing activities:
Early extinguishment of Senior Unsecured Notes		(281,490)	(209,500)
Borrowings under revolving credit facility		47,617	100,000
Repayment of revolving credit facility		(147,617)
Issuance of Convertible Senior Notes due 2032			200,000
Repurchase of Convertible Senior Notes due 2025		(3,487)	(298,288)
Proceeds from term loans		300,000	100,000
Repayment of term loans	(15,000)	(374,681)	(12,569)
Repayment of MARAD borrowings	(5,376)	(5,120)	(4,877)
Deferred financing costs	(3,586)	(10,954)	(7,580)
Distributions to noncontrolling interests	(1,018)	(4,097)	(5,287)
Repurchases of common stock	(8,382)	(11,256)	(7,197)
Excess tax from stock-based compensation	68	219	(1,186)
Exercise of stock options, net and other		734	1,252
Proceeds from issuance of ESPP shares	3,223	2,711
Net cash used in financing activities	(30,071)	(487,421)	(145,232)
Effect of exchange rate changes on cash and cash equivalents	4,390	(2,725)	(860)
Net increase (decrease) in cash and cash equivalents	(1,708)	41,100	(109,363)
Cash and cash equivalents:
Balance, beginning of year	478,200	437,100	546,463
Balance, end of year	$ 476,492	$ 478,200	$ 437,100

Organization	12 Months Ended
Organization	Dec. 31, 2014
Organization [Abstract]
Organization	Note 1 — Organization Unless the context indicates otherwise, the terms “we,” “us” and “our” in this Annual Report refer collectively to Helix Energy Solutions Group, Inc. and its subsidiaries (“Helix” or the “Company”). We are an international offshore energy services company that provides specialty services to the offshore energy industry, with a focus on well intervention and robotics operations. We conduct operations primarily in deepwater in the Gulf of Mexico, North Sea, Asia Pacific and West Africa regions. Our Operations We seek to provide services and methodologies that we believe are critical to developing offshore reservoirs and maximizing production economics. Our “life of field” services are segregated into four business segments: Well Intervention, Robotics, Production Facilities and Subsea Construction (Note 12). Our Well Intervention segment includes our vessels and equipment used to perform well intervention services primarily in the Gulf of Mexico and North Sea regions. Our well intervention vessels include the Q4000, the Helix 534, the Seawell, the Well Enhancer and the Skandi Constructor, which is a chartered vessel. Our Robotics segment currently operates four chartered vessels, and also includes ROVs, trenchers and ROVDrills designed to complement offshore construction and well intervention services. Our Production Facilities segment includes the Helix Producer I (the “HP I”) vessel (Note 5), our equity investments in Deepwater Gateway, L.L.C. (“Deepwater Gateway”) and Independence Hub, LLC (“Independence Hub”) (Note 4), and the Helix Fast Response System (the “HFRS”) which provides certain operators access to our Q4000 and HP I vessels in the event of a well control incident in the Gulf of Mexico. Discontinued Operations In December 2012, we announced a definitive agreement for the sale of Energy Resource Technology GOM, Inc. (“ERT”), a former wholly-owned U.S. subsidiary that conducted our oil and gas operations in the Gulf of Mexico. In February 2013, we sold ERT for $624 million plus additional consideration in the form of overriding royalty interests in ERT’s Wang well and certain exploration prospects. As a result, we have presented the historical operating results of our former Oil and Gas segment as discontinued operations in the accompanying consolidated financial statements. See Note 13 for additional information regarding our discontinued oil and gas operations and Note 6 regarding the use of a portion of the sale proceeds to reduce our indebtedness under our former credit agreement.

Summary Of Significant Accounting Policies

12 Months Ended

Dec. 31, 2014

Summary Of Significant Accounting Policies [Abstract]

Summary Of Significant Accounting Policies

Note 2 — Summary of Significant Accounting Policies

Principles of Consolidation

Our consolidated financial statements include the accounts of majority-owned subsidiaries. The equity method is used to account for investments in affiliates in which we do not have majority ownership, but have the ability to exert significant influence. We account for our Deepwater Gateway and Independence Hub investments under the equity method of accounting. Noncontrolling interests represent the minority shareholders’ proportionate share of the equity in Kommandor LLC (Note 5). All material intercompany accounts and transactions have been eliminated. Certain reclassifications were made to previously-reported amounts in the consolidated financial statements and notes thereto to make them consistent with the current presentation format.

Use of Estimates

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

Cash and Cash Equivalents

Cash and cash equivalents are highly liquid financial instruments with original maturities of three months or less. They are carried at cost plus accrued interest, which approximates fair value.

Statement of Cash Flow Information

The following table provides supplemental cash flow information for the periods stated (in thousands):


		Year Ended December 31,
		2014		2013		2012

Interest paid, net of interest capitalized	$	11,628	$	39,040	$	68,735
Income taxes paid	$	70,509	$	113,331	$	43,111

Our non-cash investing activities include accruals for property and equipment capital expenditures. As of December 31, 2014 and 2013, these non-cash investing accruals totaled $14.1 million and $9.5 million, respectively. Additionally, $27.5 million of our non-cash investing activities relates to the promissory note we received in connection with the sale of our Ingleside spoolbase in January 2014.

Accounts and Notes Receivable and Allowance for Uncollectible Accounts

Accounts and notes receivable are stated at the historical carrying amount net of write-offs and allowance for uncollectible accounts. The amount of our net accounts receivable and our note receivable approximates fair value. We establish an allowance for uncollectible accounts based on historical experience and any specific collection issues that we have identified. Uncollectible receivables are written off when a settlement is reached for an amount that is less than the outstanding historical balance or when we have determined that the balance will not be collected (Note 14).

Property and Equipment

Overview. Property and equipment is recorded at cost. Property and equipment is depreciated on a straight line basis over the estimated useful life of each asset. The following is a summary of the gross components of property and equipment (dollars in thousands):


	Estimated Useful Life		2014		2013

Vessels	15 to 30 years	$	1,657,448	$	1,403,573
ROVs, trenchers and ROVDrills	10 years		310,841		271,801
Machinery, equipment, buildings and leasehold improvements	5 to 30 years		273,155		288,332
Total property and equipment		$	2,241,444	$	1,963,706

The cost of repairs and maintenance is charged to expense as incurred, while the cost of improvements is capitalized. For the years ended December 31, 2014, 2013 and 2012, repair and maintenance expense totaled $44.6 million, $31.5 million and $39.3 million, respectively. Included in machinery, equipment, buildings and leasehold improvements were $17.4 million and $17.5 million of capitalized software costs ($3.9 million and $4.8 million, net of accumulated amortization) at December 31, 2014 and 2013, respectively. For the years ended December 31, 2014, 2013 and 2012, the total amount charged to expense related to the amortization of these software costs was $1.3 million, $1.8 million and $2.6 million, respectively.

Assets used in operations are assessed for impairment whenever changes in facts and circumstances indicate that the carrying amount of the asset or asset group is not recoverable and exceeds the asset’s or asset group’s fair value. If, upon review, the sum of the undiscounted future cash flows expected to be generated by the asset or asset group is less than its carrying amount, an impairment is recorded. The amount of the impairment recorded is calculated as the difference between the carrying amount of the asset or asset group and its estimated fair value. Individual assets are grouped for impairment purposes at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. Our marine vessels are assessed on a vessel by vessel basis, while our remotely operated vehicles (“ROVs”) are grouped and assessed by asset class. The expected future cash flows used for impairment reviews and related fair value calculations are based on assessments of operating costs, project margins and capital project decisions, considering all available information at the date of review. The fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants or based on a multiple of operating cash flows validated with historical market transactions of similar assets where possible. These fair value measurements fall within Level 3 of the fair value hierarchy.

In 2012, we decided to cease our well intervention operations in Australia. We recorded a $4.6 million impairment charge to reduce our well intervention assets in Australia to their fair value of $5.0 million. In 2012, as a result of diminished work opportunities for the Intrepid, we placed the subsea construction vessel in cold-stack mode and recorded an impairment of $14.6 million to reduce its carrying amount to its fair value of $28.0 million. We later sold the vessel for $14.5 million in cash, which resulted in an additional loss on disposal of $13.5 million.

Also in 2012, we entered into an agreement to sell our two remaining subsea construction pipelay vessels, the Caesar and the Express, and related pipelay equipment for a total sales price of $238.3 million. In connection with the announcement of the sale of our remaining subsea construction pipelay vessels and related equipment, we recorded an impairment of $157.8 million to reduce the carrying amount of the Caesar and related pipelay equipment to their respective fair values of $138.3 million, which reflects the consideration we expected to receive at the time of the sale. In June 2013, we completed the sale of the Caesar and related equipment and recorded an additional loss on disposal of $1.1 million. In July 2013, we completed the sale of the Express for $100 million, which resulted in a gain on disposal of $15.6 million.

In January 2014, we sold our spoolbase located in Ingleside, Texas for $45 million. In connection with this sale, we received $15 million in cash, including a $5 million deposit we received at the time the agreement was signed in December 2013. The remainder was paid to us with a $30 million secured promissory note. Interest on the note is payable quarterly at a rate of 6% per annum. We received $2.5 million and $7.5 million of principal payments on this note in December 2014 and January 2015, respectively. Under the terms of the note, the remaining $20 million principal balance is required to be paid with a $10 million payment on each December 31 of 2015 and 2016. See Note 13 for disclosure related to the impairment charges associated with certain of our former oil and gas properties.

Interest from external borrowings is capitalized on major projects until the assets are ready for their intended use. Capitalized interest is added to the cost of the underlying asset and is amortized over the useful life of the asset in the same manner as the underlying asset. The total of our interest expense capitalized during the years ended December 31, 2014, 2013 and 2012 was $10.4 million, $10.4 million and $4.9 million, respectively.

Equity Investments

We periodically review our equity investments in Deepwater Gateway and Independence Hub for impairment. Under the equity method of accounting, an impairment loss would be recorded whenever the fair value of an equity investment is determined to be below its carrying amount and the reduction is considered to be other than temporary. In judging “other than temporary,” we consider the length of time and extent to which the fair value of the investment has been less than the carrying amount of the equity investment, the near-term and long-term operating and financial prospects of the entity and our longer-term intent of retaining the investment in the entity.

Goodwill

We are required to perform an annual impairment analysis of goodwill. We elected November 1 to be our annual impairment assessment date for goodwill. However, we could be required to evaluate the recoverability of goodwill prior to the annual assessment date if we experience disruption to the business, unexpected significant declines in operating results, divestiture of a significant component of the business, emergence of unanticipated competition, loss of key personnel or a sustained decline in market capitalization. At the time of our annual assessment of goodwill on November 1, 2014, we had two reporting units with goodwill.

As allowed under the guidance, we first assess qualitative factors in order to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount, including goodwill. Some of the qualitative factors evaluated include, among other things, the results of the most recent impairment test, the most recent operating results of the reporting unit, the current outlook for the reporting unit, and the current conditions of the market in which the reporting unit operates. If the qualitative assessment indicates a potential impairment, we perform the first step of the goodwill impairment test as described below. Our policy is to bypass the qualitative assessment at least once every three years and perform the first step of the goodwill impairment test, with the latest such test occurring on November 1, 2013.

The goodwill impairment test is a two-step process. The first step is to identify if a potential impairment exists by comparing the fair value of the reporting unit with its carrying amount, including goodwill. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to have a potential impairment and the second step of the impairment test is not necessary. However, if the carrying amount of a reporting unit exceeds its fair value, the second step is performed to determine if goodwill is impaired and to measure the amount of impairment loss to recognize, if any.

The second step compares the implied fair value of goodwill with the carrying amount of goodwill. If the implied fair value of goodwill exceeds the carrying amount, then goodwill is not considered impaired. However, if the carrying amount of goodwill exceeds the implied fair value, an impairment loss is recognized in an amount equal to that excess. The implied fair value of goodwill is determined in the same manner as the amount of goodwill recognized in a business combination (i.e., the fair value of the reporting unit is allocated to all the assets and liabilities, including any unrecognized intangible assets, as if the reporting unit were acquired in a business combination).

We use both the income approach and the market approach to estimate the fair value of our reporting units under the first step of our goodwill impairment assessment. Under the income approach, a discounted cash flow analysis is performed requiring us to make various judgmental assumptions about future revenue, operating margins, growth rates and discount rates. These judgmental assumptions are based on our budgets, long-term business plans, economic projections, anticipated future cash flows and market place data. Under the market approach, the fair value of each reporting unit is calculated by applying an average peer total invested capital EBITDA (defined as earnings before interest, income taxes and depreciation and amortization) multiple to the upcoming fiscal year’s forecasted EBITDA for each reporting unit. Judgment is required when selecting peer companies that operate in the same or similar lines of business and are potentially subject to the same economic risks.

Our goodwill at December 31, 2014, 2013 and 2012 was associated with our Well Intervention and Robotics segments. In our 2013 goodwill impairment test, the fair value of both of our reporting units with goodwill exceeded their respective carrying amounts. We performed the qualitative assessment as described above in both 2012 and 2014. Based on those assessments, we concluded that there was no indication of goodwill impairment and we did not perform step one of the impairment test in either year. We did not record any amount of goodwill impairment at December 31, 2014, 2013 or 2012.

The changes in the carrying amount of goodwill are as follows (in thousands):


		Well
		Intervention		Robotics		Total

Balance at December 31, 2012	$	17,828	$	45,107	$	62,935
Other adjustments (1)		295		-		295
Balance at December 31, 2013		18,123		45,107		63,230
Other adjustments (1)		(1,084)		-		(1,084)
Balance at December 31, 2014	$	17,039	$	45,107	$	62,146

(1)

Reflects foreign currency adjustment for certain amounts of our goodwill.

Recertification Costs and Deferred Dry Dock Charges

Our vessels are required by regulation to be recertified after certain periods of time. Recertification costs are incurred while a vessel is in dry dock. In addition, routine repairs and maintenance are performed and at times, major replacements and improvements are performed. We expense routine repairs and maintenance costs as they are incurred. We defer and amortize dry dock and related recertification costs over the length of time for which we expect to receive benefits from the dry dock and related recertification, which is generally 30 months but can be as long as 60 months if the appropriate permitting is obtained. A dry dock and related recertification process typically lasts one to two months, a period during which the vessel is idle and generally not available to earn revenue. Major replacements and improvements that extend the vessel’s economic useful life or functional operating capability are capitalized and depreciated over the vessel’s remaining economic useful life.

As of December 31, 2014 and 2013, capitalized deferred dry dock charges included within “Other assets, net” in the accompanying consolidated balance sheets (Note 3) totaled $11.6 million and $20.8 million (net of accumulated amortization of $7.5 million and $14.5 million), respectively. During the years ended December 31, 2014, 2013 and 2012, dry dock amortization expense was $14.1 million, $14.8 million and $8.6 million, respectively.

Revenue Recognition

Revenues from our services are derived from contracts, which are both short-term and long-term in duration. Our long-term services contracts are contracts that contain either lump-sum, turnkey provisions or provisions for specific time, material and equipment charges, which are billed in accordance with the terms of such contracts. We recognize revenue as it is earned at estimated collectible amounts. Further, we record revenues net of taxes collected from customers and remitted to governmental authorities.

Unbilled revenue represents revenue attributable to work completed prior to period end that has not yet been invoiced. All amounts included in unbilled revenue at December 31, 2014 and 2013 are expected to be billed and collected within one year. However, we also monitor the collectability of our outstanding trade receivables on a continual basis in connection with our evaluation of allowance for doubtful accounts.

Dayrate Contracts. Revenues generated from specific time, materials and equipment contracts are generally earned on a dayrate basis and recognized as amounts are earned in accordance with contract terms. In connection with these contracts, we may receive revenues for mobilization of equipment and personnel. Revenues related to mobilization are deferred and recognized over the period in which contracted services are performed using the straight-line method. Incremental costs incurred directly for mobilization of equipment and personnel to the contracted site, which typically consist of materials, supplies and transit costs, are also deferred and recognized using the same method. Our policy to amortize the revenues and costs related to mobilization on a straight-line basis over the estimated contract service period is consistent with the general pace of activity, level of services being provided and dayrates being earned over the service period of the contract. Mobilization costs to move vessels when a contract does not exist are expensed as incurred.

Turnkey Contracts. Revenue on significant turnkey contracts is recognized under the percentage-of-completion method based on the ratio of costs incurred to total estimated costs at completion. In determining whether a contract should be accounted for using the percentage-of-completion method, we consider whether:

	•		the customer provides specifications for the provision of services;
	•		we can reasonably estimate our progress towards completion and our costs;
	•		the contract includes provisions for the enforceable rights regarding the goods or services to be provided, consideration to be received, and the manner and terms of payment;
	•		the customer can be expected to satisfy its obligations under the contract; and
	•		we can be expected to perform our contractual obligations.

Under the percentage-of-completion method, we recognize estimated contract revenue based on costs incurred to date as a percentage of total estimated costs. Changes in the expected cost of materials and labor, productivity, scheduling and other factors affect the total estimated costs. Additionally, external factors, including weather and other factors outside of our control, may affect the progress and estimated cost of a project’s completion and, therefore, the timing of revenue recognition. We routinely review estimates related to our contracts and reflect revisions to profitability in earnings on a current basis. If a current estimate of total contract cost indicates an ultimate loss on a contract, we recognize the projected loss in full when it is first determined. We recognize additional contract revenue related to claims when the claim is probable and legally enforceable.

Income Taxes

Deferred income taxes are based on the differences between financial reporting and tax bases of assets and liabilities. We utilize the liability method of computing deferred income taxes. The liability method is based on the amount of current and future taxes payable using tax rates and laws in effect at the balance sheet date. Income taxes have been provided based upon the tax laws and rates in the countries in which operations are conducted and income is earned. A valuation allowance for deferred tax assets is recorded when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. We consider the undistributed earnings of our principal non-U.S. subsidiaries to be permanently reinvested.

It is our policy to provide for uncertain tax positions and the related interest and penalties based upon management’s assessment of whether a tax benefit is more likely than not to be sustained upon examination by tax authorities. At December 31, 2014, we believe that we have appropriately accounted for any unrecognized tax benefits. To the extent we prevail in matters for which a liability for an unrecognized tax benefit is established or are required to pay amounts in excess of the liability, our effective tax rate in a given financial statement period may be affected.

Foreign Currency

Because we operate in various regions in the world, we conduct a portion of our business in currencies other than the U.S. dollar (primarily with respect to Helix Well Ops (U.K.) Limited (“WOUK”)). The functional currency for WOUK is the applicable local currency (British Pound). Results of operations for these subsidiaries are translated into U.S. dollars using average exchange rates during the period. Assets and liabilities of these foreign subsidiaries are translated into U.S. dollars using the exchange rate in effect at December 31, 2014 and 2013 and the resulting translation adjustments, which were unrealized gains (losses) of $(19.5) million and $5.0 million, respectively, are included in “Accumulated other comprehensive loss” (“Accumulated OCI”), a component of shareholders’ equity.

For the years ended December 31, 2014, 2013 and 2012, our foreign currency transaction gains (losses) totaled $2.5 million, $0.7 million and $(0.5) million, respectively. These realized amounts are exclusive of any gains or losses from our foreign currency exchange derivative contracts. All foreign currency transaction gains and losses are recognized currently in the consolidated statements of operations.

Derivative Instruments and Hedging Activities

Our operations are exposed to market risks associated with interest rates and foreign currency exchange rates. Our risk management activities involve the use of derivative financial instruments to hedge the impact of market risk exposure related to variable interest rates and foreign currency exchange rates. All derivatives are reflected in the accompanying consolidated balance sheets at fair value.

We formally document all relationships between hedging instruments and the related hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. We also assess, both at the inception of the hedge and on an on-going basis, whether the derivatives that are designated as hedges are highly effective in offsetting changes in cash flows of the hedged items. We discontinue hedge accounting if we determine that a derivative is no longer highly effective as a hedge, or it is probable that a hedged transaction will not occur. If hedge accounting is discontinued because it is probable the hedged transaction will not occur, deferred gains or losses on the hedging instruments are recognized in earnings immediately. If the forecasted transaction continues to be probable of occurring, any deferred gains or losses in accumulated other comprehensive income (loss) (a component of shareholders’ equity) are amortized to earnings over the remaining period of the original forecasted transaction.

We engage solely in cash flow hedges. Hedges of cash flow exposure are entered into to hedge a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability. Changes in the fair value of derivatives that are designated as cash flow hedges are deferred to the extent that the hedges are effective. These fair value changes are recorded as a component of Accumulated OCI until the hedged transactions occur and are recognized in earnings. The ineffective portion of changes in the fair value of cash flow hedges is recognized immediately in earnings. In addition, any change in the fair value of a derivative that does not qualify for hedge accounting is recorded in earnings in the period in which the change occurs.

Interest Rate Risk

From time to time, we enter into interest rate swaps to stabilize cash flows related to our long-term debt subject to variable interest rates. Changes in the fair value of an interest rate swap are deferred to the extent the swap is effective. These changes are recorded as a component of Accumulated OCI until the anticipated interest payments occur and are recognized in interest expense. The ineffective portion of the interest rate swap, if any, is recognized immediately in earnings within the line titled “Net interest expense.” The amount of ineffectiveness associated with our interest rate swap contracts was immaterial for all periods presented.

Foreign Currency Exchange Rate Risk

Because we operate in various regions in the world, we conduct a portion of our business in currencies other than the U.S. dollar. We entered into various foreign currency exchange contracts to stabilize expected cash outflows relating to certain vessel charters that are denominated in British pounds and Norwegian kroner. At December 31, 2014 and 2013, the aggregate fair value of the foreign exchange contracts was a net liability of $50.4 million and $15.0 million, respectively.

See Note 15 for more information regarding the accounting for our derivative contracts including our oil and gas commodity contracts associated with ERT.

Earnings Per Share

The presentation of basic EPS amounts on the face of the accompanying consolidated statements of operations is computed by dividing the net income applicable to our common shareholders by the weighted average shares of our outstanding common stock. The calculation of diluted EPS is similar to basic EPS, except that the denominator includes dilutive common stock equivalents and the income included in the numerator excludes the effects of the impact of dilutive common stock equivalents, if any. We have shares of restricted stock issued and outstanding, which currently are unvested. Holders of such shares of unvested restricted stock are entitled to the same liquidation and dividend rights as the holders of our outstanding unrestricted common stock and the shares are thus considered participating securities. Under applicable accounting guidance, the undistributed earnings for each period are allocated based on the participation rights of both the common shareholders and holders of any participating securities as if earnings for the respective periods had been distributed. Because both the liquidation and dividend rights are identical, the undistributed earnings are allocated on a proportionate basis. Further, we are required to compute earnings per share (“EPS”) amounts under the two class method in periods in which we have earnings from continuing operations. For periods in which we have a net loss, we do not use the two class method as holders of our restricted shares are not contractually obligated to share in such losses.

The computations of the numerator (income) and denominator (shares) to derive the basic and diluted EPS amounts presented on the face of the accompanying consolidated statements of operations for the years ended December 31, 2014, 2013 and 2012 are as follows (in thousands):


		Year Ended December 31,
		2014			2013			2012
		Income	Shares		Income	Shares		Income	Shares
Basic:
Continuing operations:
Net income applicable to Helix	$	195,047		$	109,922		$	(46,334)
Less: Income from discontinued operations, net of tax		-			(1,073)			(23,684)
Net income from continuing operations		195,047			108,849			(70,018)
Less: Undistributed income allocable to participating securities – continuing operations		(1,018)			(801)			-
Net income applicable to common shareholders – continuing operations	$	194,029	105,029	$	108,048	105,032	$	(70,018)	104,449


Discontinued operations:
Income from discontinued operations, net of tax	$	-		$	1,073		$	23,684
Less: Undistributed income allocable to participating securities – discontinued operations		-			(8)			-
Net income applicable to common shareholders – discontinued operations	$	-	105,029	$	1,065	105,032	$	23,684	104,449


		Year Ended December 31,
		2014			2013			2012
		Income	Shares		Income	Shares		Income	Shares
Diluted:
Continuing operations:
Net income applicable to common shareholders – continuing operations	$	194,029	105,029	$	108,048	105,032	$	(70,018)	104,449
Effect of dilutive securities:
Share-based awards other than participating securities		-	16		-	152		-	-
Undistributed income reallocated to participating securities		-	-		1	-		-	-
Net income applicable to common shareholders – continuing operations	$	194,029	105,045	$	108,049	105,184	$	(70,018)	104,449

Discontinued operations:
Income from discontinued operations, net of tax	$	-	105,045	$	1,073	105,184	$	23,684	104,449

We had net losses from continuing operations for the year ended December 31, 2012. Accordingly, our diluted EPS calculation for 2012 was equivalent to our basic EPS calculation because it excluded any assumed exercise or conversion of common stock equivalents because they were deemed to be anti-dilutive, meaning their inclusion would have reduced the reported net loss per share in those respective years. Shares that otherwise would have been included in the diluted per share calculations for the year ended December 31, 2012, assuming we had earnings from continuing operations, are as follows (in thousands):


		2012

Diluted shares (as reported)		104,449
Share-based awards		382
Convertible preferred stock		334
Total		105,165

In addition, approximately 8.0 million of potentially dilutive shares related to our Convertible Senior Notes Due 2032 (the “2032 Notes”) were excluded from the diluted EPS calculation for the years ended December 31, 2014 and 2013 because we have the right and the intention to settle any such future conversions in cash (Note 6). Approximately 9.3 million of potentially dilutive shares related to our Convertible Senior Notes Due 2025 (the “2025 Notes”) then outstanding were excluded for the year ended December 31, 2012 as the conversion trigger of $38.57 per share was not met.

Major Customers and Concentration of Credit Risk

The market for our products and services is primarily the offshore oil and gas industry. Oil and gas companies spend capital on exploration, drilling and production operations, the amount of which is generally dependent on the prevailing view of future oil and gas prices that are subject to many external factors which may contribute to significant volatility. Our customers consist primarily of major and independent oil and gas producers and suppliers, pipeline transmission companies, alternative (renewable) energy companies and offshore engineering and construction firms. We perform ongoing credit evaluations of our customers and provide allowances for probable credit losses when necessary. The percent of consolidated revenue from major customers (those representing 10% or more of our consolidated revenues) is as follows: 2014 — Anadarko (13%); 2013 — Shell (14%) and 2012 — Shell (12%). Most of the revenues from Shell were generated by our Well Intervention segment.

Fair Value Measurements

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The fair value accounting rules establish a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value as follows:


	•		Level 1. Observable inputs such as quoted prices in active markets;
	•		Level 2. Inputs, other than the quoted prices in active markets, that are observable either directly or indirectly; and
	•		Level 3. Unobservable inputs for which there is little or no market data, which require the reporting entity to develop its own assumptions.

Assets and liabilities measured at fair value are based on one or more of three valuation techniques as follows:

(a)

Market Approach. Prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities.

(b)

Cost Approach. Amount that would be required to replace the service capacity of an asset (replacement cost).

(c)

Income Approach. Techniques to convert expected future cash flows to a single present amount based on market expectations (including present value techniques, option-pricing and excess earnings models).

Our financial instruments include cash and cash equivalents, accounts receivable, accounts payable, long-term debt and various derivative instruments. The carrying amount of cash and cash equivalents, accounts receivable and accounts payable approximates fair value due to the highly liquid nature of these instruments. The following tables provide additional information related to other financial instruments measured at fair value on a recurring basis (in thousands):


		Fair Value Measurements at
		December 31, 2014 Using							Valuation
		Level 1		Level 2 (1)		Level 3		Total	Technique
Assets:
Interest rate swaps	$	-	$	369	$	-	$	369	(c)

Liabilities:
Fair value of long-term debt (2)		222,900		375,393		-		598,293	(a)
Foreign exchange contracts		-		50,428		-		50,428	(c)
Interest rate swaps		-		561		-		561	(c)
Total net liability	$	222,900	$	426,013	$	-	$	648,913


		Fair Value Measurements at
		December 31, 2013 Using							Valuation
		Level 1		Level 2 (1)		Level 3		Total	Technique
Assets:
Foreign exchange contracts	$	-	$	69	$	-	$	69	(c)
Interest rate swaps		-		446		-		446	(c)

Liabilities:
Fair value of long-term debt (2)		242,250		403,437		-		645,687	(a)
Foreign exchange contracts		-		15,071		-		15,071	(c)
Interest rate swaps		-		746		-		746	(c)
Total net liability	$	242,250	$	418,739	$	-	$	660,989

(1) Unless otherwise indicated, the fair value of our Level 2 derivative instruments reflects our best estimate and is based upon exchange or over-the-counter quotations whenever they are available. Quoted valuations may not be available due to location differences or terms that extend beyond the period for which quotations are available. Where quotes are not available, we utilize other valuation techniques or models to estimate market values. These modeling techniques require us to make estimations of future prices, price correlation and market volatility and liquidity based on market data. Our actual results may differ from our estimates, and these differences could be positive or negative. See Note 15 for further discussion on fair value of our derivative instruments.

(2) See Note 6 for additional information regarding our long-term debt. The value of our long-term debt at December 31, 2014 and 2013 is as follows (in thousands):


		2014				2013
		Carrying		Fair		Carrying		Fair
		Amount		Value (b)		Amount		Value (b)

Term Loan (matures June 2018)	$	277,500	$	270,563	$	292,500	$	293,963
2032 Notes (mature March 2032) (a)		200,000		222,900		200,000		242,250
MARAD Debt (matures February 2027)		94,792		104,830		100,168		109,474
Total debt	$	572,292	$	598,293	$	592,668	$	645,687

(a) Carrying amount excludes the related unamortized debt discount of $20.9 million and $26.5 million at December 31, 2014 and 2013, respectively.

(b) The estimated fair value of the 2032 Notes was determined using Level 1 inputs under the market approach. The fair value of the Term Loan and the MARAD Debt was estimated using Level 2 fair value inputs under the market approach. The fair value of the Term Loan and the MARAD debt was determined using a third party evaluation of the remaining average life and outstanding principal balance of the indebtedness as compared to other obligations in the marketplace with similar terms.

Debt Discount

In connection with the issuance of the 2032 Notes, we recorded a discount of $35.4 million under existing accounting requirements. To arrive at this discount amount, we estimated the fair value of the liability component of the 2032 Notes as of the date of their issuance (March 12, 2012) using an income approach. To determine this estimated fair value, we used borrowing rates of similar market transactions involving comparable liabilities at the time of issuance and an expected life of 6.0 years. In selecting the expected life, we selected the earliest date that the holders could require us to repurchase all or a portion of the 2032 Notes (March 15, 2018). The remaining unamortized amount of the discount of the 2032 Notes was $20.9 million and $26.5 million at December 31, 2014 and 2013, respectively (Note 6).

Convertible Preferred Stock

In December 2012, the holder of the remaining $1 million of Convertible Preferred Stock converted it into 361,402 shares of our common stock. Our Convertible Preferred Stock was assessed for inclusion in our diluted earnings per share calculation using the if converted method (see “Earnings Per Share”) above.

Related Party Transactions

Our Chief Executive Officer, Owen Kratz, through Class A limited partnership interests in OKCD Investments, Ltd. (“OKCD”), personally owns approximately 85% of the partnership. OKCD receives a royalty from ERT, which was a wholly owned subsidiary of Helix until ERT was sold in February 2013. Payments to OKCD during the period in which Helix owned ERT totaled $0.6 million in 2013.

New Accounting Standards

In May 2014, the Financial Accounting Standards Board issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” This ASU provides a single five-step approach to account for revenue arising from contracts with customers. The ASU requires entities to recognize revenue in a way that depicts the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This guidance is effective prospectively for annual reporting periods beginning after December 15, 2016, including interim periods. Early adoption is not permitted. The guidance permits companies to either apply the requirements retrospectively to all prior periods presented, or apply the requirements in the year of adoption through a cumulative adjustment. We are currently evaluating which transition approach to use and the potential impact the adoption of this new standard may have on our consolidated financial statements.

We do not expect any other recent accounting standards to have a material impact on our financial position, results of operations or cash flows.

- Definition

The entire disclosure for all significant accounting policies of the reporting entity.

+ References+ Details

Details Of Certain Accounts

12 Months Ended

Dec. 31, 2014

Details Of Certain Accounts [Abstract]

Details Of Certain Accounts

Note 3 — Details of Certain Accounts

Other current assets consisted of the following as of December 31, 2014 and 2013 (in thousands):


		2014		2013

Note receivable (1)	$	17,500	$	-
Other receivables		423		785
Prepaid insurance		6,582		7,038
Other prepaids		15,541		12,999
Spare parts inventory		1,857		1,038
Value added tax receivable		9,326		7,589
Other		72		260
Total other current assets	$	51,301	$	29,709

Other assets, net, consisted of the following as of December 31, 2014 and 2013 (in thousands):


		2014		2013

Note receivable (1)	$	10,000	$	-
Deferred dry dock expenses, net (Note 2)		11,631		20,833
Deferred financing costs, net (Note 6)		23,399		24,297
Intangible assets with finite lives, net		696		622
Charter fee deposit (Note 11)		12,544		-
Other		1,002		1,515
Total other assets, net	$	59,272	$	47,267

(1)

Relates to the remaining balance of the promissory note we received in connection with the sale of our Ingleside spoolbase in January 2014 (Note 2).

Accrued liabilities consisted of the following as of December 31, 2014 and 2013 (in thousands):


		2014		2013

Accrued payroll and related benefits	$	61,246	$	50,527
Current asset retirement obligations		575		2,024
Unearned revenue		11,461		19,608
Billing in excess of cost		-		1,677
Accrued interest		4,221		4,187
Derivative liability (Note 15)		13,222		2,651
Taxes payable excluding income tax payable		6,236		4,811
Pipelay assets sale deposit		-		5,000
Other		7,962		5,997
Total accrued liabilities	$	104,923	$	96,482

Equity Investments

12 Months Ended

Dec. 31, 2014

Equity Investments [Abstract]

Equity Investments

Note 4 — Equity Investments

As of December 31, 2014, we had two investments that we account for using the equity method of accounting: Deepwater Gateway and Independence Hub, both of which are included in our Production Facilities segment.

Deepwater Gateway, L.L.C. In June 2002, we, along with Enterprise Products Partners L.P. (”Enterprise”), formed Deepwater Gateway, each with a 50% interest, to design, construct, install, own and operate a tension leg platform production hub primarily for Anadarko Petroleum Corporation's Marco Polo field in the Deepwater Gulf of Mexico. As of December 31, 2014 and 2013, our investment in Deepwater Gateway totaled $80.9 million and $85.8 million (including net capitalized interest of $1.2 million and $1.3 million), respectively.

Independence Hub, LLC. In December 2004, we acquired a 20% interest in Independence Hub, an affiliate of Enterprise. Independence Hub owns the "Independence Hub" platform located in Mississippi Canyon Block 920 in a water depth of 8,000 feet. As of December 31, 2014 and 2013, our investment in Independence Hub was $68.8 million and $72.1 million (including net capitalized interest of $3.9 million and $4.3 million), respectively.

We received the following distributions from our equity method investments during the years ended December 31, 2014, 2013 and 2012 (in thousands):


		Year Ended December 31,
		2014		2013		2012

Deepwater Gateway	$	6,150	$	7,600	$	8,157
Independence Hub		2,640		4,660		8,073
Total	$	8,790	$	12,260	$	16,230

- Definition

The entire disclosure for equity method investments and joint ventures. Equity method investments are investments that give the investor the ability to exercise significant influence over the operating and financial policies of an investee. Joint ventures are entities owned and operated by a small group of businesses as a separate and specific business or project for the mutual benefit of the members of the group.

+ References+ Details

Kommandor LLC	12 Months Ended
Kommandor LLC	Dec. 31, 2014
Kommandor LLC [Abstract]
Kommandor LLC	Note 5 — Kommandor LLC In October 2006, we partnered with Kommandor RØMØ, a Danish corporation, to form Kommandor LLC, a Delaware limited liability company, the purpose of which was to convert a ferry vessel into a ship-shaped dynamically-positioned floating production unit vessel. Upon completion of the conversion in April 2009, the vessel (the HP I) was leased to us under a bareboat charter. We subsequently installed topside oil and gas processing equipment, at 100% our cost, that allows the HP I to serve as a floating production system primarily servicing fields in the Deepwater of the Gulf of Mexico. In June 2010, the HP I was certified for use as a floating production unit by the U.S. Coast Guard. The HP I initially participated in the Macondo well control and containment efforts. Subsequently, the HP I mobilized to the Phoenix field where production commenced in October 2010. The HP I is under contract with ERT to service the Phoenix field through at least December 31, 2016. The consolidated results of Kommandor LLC are included in our Production Facilities segment. We owned approximately 81% of Kommandor LLC at December 31, 2013. In February 2014, we acquired Kommandor RØMØ’s noncontrolling interest (approximately 19%) in Kommandor LLC for $20.1 million.

Long-Term Debt

12 Months Ended

Dec. 31, 2014

Long-Term Debt [Abstract]

Long-Term Debt

Note 6 — Long-Term Debt

Long-term debt consisted of the following as of December 31, 2014 and 2013 (in thousands):


		2014		2013

Term Loan (matures June 2018)	$	277,500	$	292,500
2032 Notes (mature March 2032)		200,000		200,000
MARAD Debt (matures February 2027)		94,792		100,168
Unamoritized debt discount		(20,920)		(26,516)
Total debt		551,372		566,152
Less current maturities		(28,144)		(20,376)
Long-term debt	$	523,228	$	545,776

Credit Agreement

In June 2013, we entered into a Credit Agreement (the “Credit Agreement”) with a group of lenders pursuant to which we borrowed $300 million under the Credit Agreement’s term loan (the “Term Loan”) component and may borrow revolving loans (the “Revolving Loans”) and/or obtain letters of credit under a revolving credit facility up to an outstanding amount of $600 million (the “Revolving Credit Facility”). Subject to customary conditions, we may request an increase of up to $200 million in aggregate commitments with respect to the Revolving Credit Facility, additional term loans or a combination thereof. The $300 million we borrowed under the Term Loan in 2013 was in connection with our early redemption of the remaining $275 million Senior Unsecured Notes outstanding in July 2013 (see “Senior Unsecured Notes” below). At December 31, 2014, our availability under the Revolving Credit Facility totaled $583.6 million, net of $16.4 million of letters of credit issued.

The Term Loan and the Revolving Loans (together, the “Loans”) will bear interest, at our election, in relation to either the base rate established by Bank of America N.A. or to a LIBOR rate, provided that all Swing Line Loans (as defined in the Credit Agreement) will be base rate loans.

The Loans or portions thereof bearing interest at the base rate will bear interest at a per annum rate equal to the base rate plus a margin ranging from 1.00% to 2.00%. The Loans or portions thereof bearing interest at a LIBOR rate will bear interest at the LIBOR rate selected by us plus a margin ranging from 2.00% to 3.00%. A letter of credit fee is payable by us equal to our applicable margin for LIBOR rate Loans multiplied by the daily amount available to be drawn under outstanding letters of credit. Margins on the Loans will vary in relation to the consolidated coverage ratio, as provided by the Credit Agreement. We currently also pay a fixed commitment fee of 0.375% on the unused portion of our Revolving Credit Facility. The Term Loan currently bears interest at the one-month LIBOR rate plus 2.25%. In September 2013, we entered into various interest rate swap contracts to fix the one-month LIBOR rate on $148.1 million of the Term Loan (Note 15). The fixed LIBOR rates were between 74 and 75 basis points.

The Term Loan is repayable in scheduled principal installments of 5% in each of the initial two loan years ($15 million per year), and 10% in each of the remaining three loan years ($30 million per year), payable quarterly, with a balloon payment of $180 million at maturity. These installment amounts are subject to adjustment for any prepayments on the Term Loan. We may elect to prepay amounts outstanding under the Term Loan without premium or penalty, but may not reborrow any amounts prepaid. We may prepay amounts outstanding under the Revolving Loans without premium or penalty, and may reborrow any amounts paid up to the amount of the Revolving Credit Facility. The Loans mature on June 19, 2018. In certain circumstances, we will be required to prepay the Loans.

The Credit Agreement and the other documents entered into in connection with the Credit Agreement (together, the “Loan Documents”) include terms and conditions, including covenants, which we consider customary for this type of transaction. The covenants include restrictions on our and our subsidiaries’ ability to grant liens, incur indebtedness, make investments, merge or consolidate, sell or transfer assets, pay dividends and incur capital expenditures. In addition, the Credit Agreement obligates us to meet certain financial ratios, including the Consolidated Interest Coverage Ratio and the Consolidated Leverage Ratio (as defined in the Credit Agreement). We have designated five of our foreign subsidiaries, and may designate any newly established foreign subsidiaries, as subsidiaries that are not generally subject to the covenants in the Credit Agreement (the “Unrestricted Subsidiaries”), provided we meet certain liquidity requirements, in which case EBITDA of the Unrestricted Subsidiaries is not included in the calculations with respect to our financial covenants. Our obligations under the Credit Agreement are guaranteed by our wholly-owned domestic subsidiaries (except Cal Dive I – Title XI, Inc.) and Canyon Offshore Limited. Our obligations under the Credit Agreement, and of the guarantors under their guaranty, are secured by most of our assets and assets of the guarantors and Canyon Offshore Limited, plus pledges of up to two-thirds of the shares of certain foreign subsidiaries.

Convertible Senior Notes Due 2032

In March 2012, we completed a public offering and sale of $200.0 million in aggregate principal amount of 3.25% Convertible Senior Notes due 2032. The net proceeds from the issuance of the 2032 Notes were $195.0 million, after deducting the underwriter’s discounts and commissions and offering expenses. We used the net proceeds to repurchase and retire $142.2 million of aggregate principal amount of the 2025 Notes (see below) in separate, privately negotiated transactions. The remaining net proceeds were used for other general corporate purposes, including the repayment of other indebtedness.

The 2032 Notes bear interest at a rate of 3.25% per annum, and are payable semi-annually in arrears on March 15 and September 15 of each year, beginning on September 15, 2012. The 2032 Notes will mature on March 15, 2032 unless earlier converted, redeemed or repurchased. The 2032 Notes are convertible in certain circumstances and during certain periods at an initial conversion rate of 39.9752 shares of common stock per $1,000 principal amount (which represents an initial conversion price of approximately $25.02 per share of common stock), subject to adjustment in certain circumstances as set forth in the Indenture governing the 2032 Notes. We have the right and the intention to settle any such future conversions in cash.

Prior to March 20, 2018, the 2032 Notes are not redeemable. On or after March 20, 2018, we, at our option, may redeem some or all of the 2032 Notes in cash, at any time upon at least 30 days’ notice, at a price equal to 100% of the principal amount plus accrued and unpaid interest (including contingent interest, if any) up to but excluding the redemption date. In addition, the holders of the 2032 Notes may require us to purchase in cash some or all of their 2032 Notes at a repurchase price equal to 100% of the principal amount of the 2032 Notes, plus accrued and unpaid interest (including contingent interest, if any) up to but excluding the applicable repurchase date, on March 15, 2018, March 15, 2022 and March 15, 2027, or, subject to specified exceptions, at any time prior to the 2032 Notes’ maturity following a fundamental change (as defined in the Indenture governing the 2032 Notes).

In connection with the issuance of the 2032 Notes, we recorded a discount of $35.4 million as required under existing accounting rules. To arrive at this discount amount, we estimated the fair value of the liability component of the 2032 Notes as of the date of their issuance (March 12, 2012) using an income approach. To determine this estimated fair value, we used borrowing rates of similar market transactions involving comparable liabilities at the time of issuance and an expected life of 6.0 years. In selecting the expected life, we selected the earliest date upon which the holders could require us to repurchase all or a portion of the 2032 Notes (March 15, 2018). The effective interest rate for the 2032 Notes is 6.9% after considering the effect of the accretion of the related debt discount that represented the equity component of the 2032 Notes at their inception. As of December 31, 2014, the carrying amount of the equity component of the 2032 Notes was $22.5 million.

MARAD Debt

This U.S. government guaranteed financing (the "MARAD Debt") is pursuant to Title XI of the Merchant Marine Act of 1936 administered by the Maritime Administration, and was used to finance the construction of the Q4000. The MARAD Debt is payable in equal semi-annual installments beginning in August 2002 and matures in February 2027. The MARAD Debt is collateralized by the Q4000, is guaranteed 50% by us, and initially bore interest at a floating rate that approximated AAA Commercial Paper yields plus 20 basis points. As provided for in the MARAD Debt agreements, in September 2005, we fixed the interest rate on the debt through the issuance of a 4.93% fixed-rate note with the same maturity date.

Nordea Credit Agreement

In September 2014, our wholly-owned subsidiary, Helix Q5000 Holdings S.à r.l. (“Q5000 Holdings”), a Luxembourg entity, entered into a Credit Agreement (the “Nordea Credit Agreement”) with a syndicated bank lending group for a term loan (the “Nordea Term Loan”) in an amount of up to $250 million. The Nordea Term Loan will be funded at or near the time of the delivery of the Q5000, which is currently estimated in the second quarter of 2015. The parent company of Q5000 Holdings, Helix Vessel Finance S.à r.l., has guaranteed the Nordea Term Loan. The loan will be secured by the Q5000 and its charter earnings as well as by a pledge of the shares of Q5000 Holdings. This indebtedness is nonrecourse to Helix.

The Nordea Term Loan will bear interest at a LIBOR rate plus a margin of 2.5%, with an undrawn fee of 0.875%. The Nordea Term Loan matures five years after funding and is repayable in scheduled principal installments of $8.9 million, payable quarterly, with a balloon payment of $80.4 million at maturity. Installment amounts are subject to adjustment for any prepayments on this debt. Q5000 Holdings may elect to prepay amounts outstanding under the Nordea Term Loan without premium or penalty, but may not reborrow any amounts prepaid. In certain circumstances, Q5000 Holdings will be required to prepay the loan.

The Nordea Credit Agreement and the other related loan documents include terms and conditions, including covenants that are considered customary for this type of transaction. The covenants include restrictions on Q5000 Holdings’s ability to grant liens, incur indebtedness, make investments, merge or consolidate, sell or transfer assets, and pay dividends. In addition, the Nordea Credit Agreement obligates Q5000 Holdings to meet minimum financial requirements, including liquidity, consolidated debt service coverage and collateral maintenance.

Former Credit Facility

Similar to our current Credit Agreement, our former credit facility contained both term loan and revolving loan components. This indebtedness was scheduled to mature on July 1, 2015. In February 2013, we repaid $318.4 million of borrowings outstanding under this former credit facility with the proceeds from the sale of ERT. We fully repaid the remaining indebtedness outstanding under this credit facility in June 2013. In connection with the repayments of this debt, we recorded charges totaling $3.5 million to accelerate a pro rata portion of the deferred financing costs associated with our former term loan debt. This charge is reflected as a component of “Loss on early extinguishment of long-term debt” in the accompanying consolidated statements of operations.

Senior Unsecured Notes

In December 2007, we issued $550 million of 9.5% Senior Unsecured Notes due 2016 (the “Senior Unsecured Notes”). In March 2012, we purchased $200.0 million of the balance then outstanding of the Senior Unsecured Notes. For this purchase, we paid a total of $213.5 million, including $200.0 million in principal, a $9.5 million call premium and $4.0 million of accrued and unpaid interest. This purchase resulted in a loss on early extinguishment of debt totaling $11.5 million, which reflects the $9.5 million call premium and a $2.0 million charge to accelerate a pro rata portion of the deferred financing costs associated with the issuance of the Senior Unsecured Notes. The loss on this early extinguishment of these notes is reflected as a component of “Loss on early extinguishment of long-term debt” in the accompanying consolidated statements of operations.

We had $275.0 million of the Senior Unsecured Notes outstanding at the beginning of 2013. In July 2013, we paid $282.0 million to fully redeem the remaining Senior Unsecured Notes, including $275.0 million with respect to the principal amount outstanding, $6.5 million of call premium and $0.5 million in accrued and unpaid interest. Our 2013 results of operations include a loss on early extinguishment of debt totaling $8.6 million, which reflects the $6.5 million call premium and a $2.1 million charge to accelerate the remaining deferred financing costs associated with the original issuance of the Senior Unsecured Notes.

Convertible Senior Notes Due 2025

In March 2005, we issued $300 million of 3.25% Convertible Senior Notes due 2025 at 100% of the principal amount to certain qualified institutional buyers. The effective interest rate for the 2025 Notes was 6.6% after considering the effect of the accretion of the related debt discount that represented the equity component of the 2025 Notes at their inception.

In connection with the issuance of additional Convertible Senior Notes (see “Convertible Senior Notes Due 2032” above) in March 2012, we repurchased $142.2 million in aggregate principal of the 2025 Notes. In these repurchase transactions, we paid an aggregate amount of $145.1 million, representing principal plus $1.8 million of premium and $1.1 million of accrued interest. The loss on this early extinguishment of the 2025 Notes totaled $5.6 million and is reflected as a component of “Loss on early extinguishment of long-term debt” in the accompanying consolidated statements of operations. The loss includes the acceleration of $3.5 million of unamortized discount associated with the 2025 Notes, the $1.8 million premium paid in connection with the repurchase of a portion of the 2025 Notes and a $0.3 million charge to accelerate a pro rata portion of the deferred financing costs associated with the original issuance of the 2025 Notes. The remainder of the 2025 Notes was extinguished when the holders exercised their option for us to repurchase their notes in December 2012 ($154.3 million) and in February 2013 when we repurchased the remaining $3.5 million of the 2025 Notes that were not put to us in December 2012.

Other

In accordance with our Credit Agreement, the 2032 Notes, the MARAD Debt agreements, and the Nordea Credit Agreement, we are required to comply with certain covenants, including certain financial ratios such as a consolidated interest coverage ratio and consolidated leverage ratio, as well as the maintenance of minimum net worth, working capital and debt-to-equity requirements. As of December 31, 2014, we were in compliance with these covenants.

We paid financing costs associated with our debt totaling $3.6 million in 2014 and $11.0 million in 2013. Unamortized deferred financing costs are included in “Other assets, net” in the accompanying consolidated balance sheets and are amortized over the life of the respective debt agreements. The following table reflects the components of our deferred financing costs for the years ended December 31, 2014 and 2013 (in thousands):


		December 31, 2014						December 31, 2013
		Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net

Term Loan (matures June 2018) (1)	$	3,638	$	(1,091)	$	2,547	$	3,638	$	(364)	$	3,274
Revolving Credit Facility (matures June 2018) (1)		13,275		(3,982)		9,293		13,275		(1,327)		11,948
2032 Notes (mature March 2032)		3,759		(1,763)		1,996		3,759		(1,148)		2,611
MARAD Debt (matures February 2027)		12,200		(6,223)		5,977		12,200		(5,736)		6,464
Nordea Term Loan		3,586		-		3,586		-		-		-
Total deferred financing costs	$	36,458	$	(13,059)	$	23,399	$	32,872	$	(8,575)	$	24,297

(1) Relates to amounts allocated to the existing Term Loan and Revolving Credit Facility, which became effective in June 2013.

Scheduled maturities of long-term debt outstanding as of December 31, 2014 are as follows (in thousands):


		Term Loan		MARAD Debt		2032 Notes (1)		Total

Less than one year	$	22,500	$	5,644	$	-	$	28,144
One to two years		30,000		5,926		-		35,926
Two to three years		30,000		6,222		-		36,222
Three to four years		195,000		6,532		-		201,532
Four to five years		-		6,858		-		6,858
Over five years		-		63,610		200,000		263,610
Total debt		277,500		94,792		200,000		572,292
Current maturities		(22,500)		(5,644)		-		(28,144)
Long-term debt, less current maturities		255,000		89,148		200,000		544,148
Unamortized debt discount (2)		-		-		(20,920)		(20,920)
Long-term debt	$	255,000	$	89,148	$	179,080	$	523,228

(1) Beginning in March 2018, the holders of the 2032 Notes may require us to repurchase these notes or we may at our option elect to repurchase these notes. The notes will mature in March 2032.

(2) The 2032 Notes will increase to their face amount through accretion of non-cash interest charges through March 2018.

The following table details the components of our net interest expense for the years ended December 31, 2014, 2013 and 2012 (in thousands):


		Year Ended December 31,
		2014		2013		2012

Interest expense (1)	$	33,064	$	44,484	$	53,601
Interest income		(4,786)		(1,167)		(548)
Capitalized interest		(10,419)		(10,419)		(4,893)
Net interest expense	$	17,859	$	32,898	$	48,160

(1)

Interest expense of $2.8 million and $28.6 million was allocated to ERT during the years ended December 31, 2013 and 2012, respectively, and is included in discontinued operations. Following the sale of ERT in February 2013, we ceased allocation of interest expense to ERT, which then constituted a discontinued operation

- Definition

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

+ References+ Details

Income Taxes

12 Months Ended

Dec. 31, 2014

Income Taxes [Abstract]

Income Taxes

Note 7 — Income Taxes

We and our subsidiaries file a consolidated U.S. federal income tax return. We believe that our recorded assets and liabilities are reasonable; however, tax laws and regulations are subject to interpretation and tax litigation is inherently uncertain, and therefore our assessments can involve a series of complex judgments about future events and rely heavily on estimates and assumptions.

Components of income tax provision (benefit) on continuing operations reflected in the consolidated statements of operations consisted of the following (in thousands):


		Year Ended December 31,
		2014		2013		2012

Current	$	43,817	$	57,128	$	6,572
Deferred		23,154		(25,516)		(65,730)
	$	66,971	$	31,612	$	(59,158)


Domestic	$	29,613	$	11,615	$	(78,211)
Foreign		37,358		19,997		19,053
	$	66,971	$	31,612	$	(59,158)

Components of income (loss) before income taxes are as follows (in thousands):


		Year Ended December 31,
		2014		2013		2012

Domestic	$	73,700	$	36,176	$	(256,859)
Foreign		188,821		107,412		130,861
	$	262,521	$	143,588	$	(125,998)

Income taxes have been provided based on the U.S. statutory rate of 35% and at the local statutory rate for each foreign jurisdiction adjusted for items that are allowed as deductions for federal and foreign income tax reporting purposes, but not for book purposes. The primary differences between the statutory rate and our effective rate from continuing operations are as follows:


	Year Ended December 31,
	2014		2013		2012

Statutory rate	35.0	%	35.0	%	35.0	%
Foreign provision	(9.1)		(11.6)		11.2
Other	(0.4)		(1.4)		0.8
Effective rate	25.5	%	22.0	%	47.0	%

Deferred income taxes result from the effect of transactions that are recognized in different periods for financial and tax reporting purposes. The nature of these differences and the income tax effect of each as of December 31, 2014 and 2013 are as follows (in thousands):


		2014		2013
Deferred tax liabilities:
Depreciation	$	211,903	$	169,404
Original Issue Discount on 2032 Notes		16,269		14,720
Equity investments in production facilities		50,685		84,870
Prepaid and other		4,211		7,556
Total deferred tax liabilities	$	283,068	$	276,550

Deferred tax assets:
Net operating losses	$	(23,076)	$	(40,105)
Reserves, accrued liabilities and other		(53,973)		(44,999)
Total deferred tax assets		(77,049)		(85,104)
Valuation allowance		23,076		22,860

Net deferred tax liabilities	$	229,095	$	214,306

Deferred income tax is presented as:
Current deferred tax assets		(31,180)		(51,573)
Noncurrent deferred tax liabilities		260,275		265,879
Net deferred tax liabilities	$	229,095	$	214,306

At December 31, 2014, we had a $23.1 million valuation allowance related to certain non-U.S. deferred tax assets, primarily net operating losses generated in Australia, as management believes it is more likely than not that we will not be able to utilize the tax benefit. Additional valuation allowances may be made in the future if in management’s opinion it is more likely than not that the tax benefit will not be utilized.

We consider the undistributed earnings of our principal non-U.S. subsidiaries to be permanently reinvested. At December 31, 2014 and 2013, our principal non-U.S. subsidiaries had accumulated earnings and profits of approximately $338.0 million and $202.6 million, respectively. We have not provided deferred U.S. income tax on the accumulated earnings and profits as we consider them permanently reinvested.

We had no uncertain tax positions as of December 31, 2014. We account for tax-related interest in interest expense and tax penalties in selling, general and administrative expenses. We accrued $0.2 million for interest in each of 2012 and 2013, which brought our total liabilities for interest and penalties to $1.3 million in the accompanying consolidated balance sheet at December 31, 2013. At both December 31, 2013 and 2012, we had $3.4 million of unrecognized tax benefits that if recognized would have affected the annual effective rate. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows (in thousands):


		2014		2013		2012

Balance at January 1,	$	4,723	$	4,506	$	7,085
Additions for tax positions of prior years		-		217		206
Reductions for tax positions of prior years		(4,723)		-		(2,785)
Balance at December 31,	$	-	$	4,723	$	4,506

In 2012, we reversed a $2.8 million long-term liability originally recorded in 2011 related to an uncertain tax position that we ultimately did not take when the 2011 tax return was filed. In 2014, we recognized a $3.4 million tax benefit as a result of the completion of examination procedures for the 2006 through 2010 audit period by the U.S. Internal Revenue Service (“IRS”) (see below). In connection with the recognition of that benefit, we reversed approximately $1.3 million of accrued interest and penalties.

We file tax returns in the U.S. and in various state, local and non-U.S. jurisdictions. We anticipate that any potential adjustments to our state, local and non-U.S. jurisdiction tax returns by tax authorities would not have a material impact on our financial position. In June 2014, the IRS and the Joint Committee on Taxation completed the examination procedures including all appeals and administrative reviews that the taxing authorities are required and expected to perform for the 2006 through 2010 audit period, and in September 2014, we received an income tax refund in the amount of $35.2 million. The refund was primarily attributable to the utilization of a net operating loss carryback from 2010. The tax periods from 2006 through 2014 remain open to review and examination by the IRS. In non-U.S. jurisdictions, the open tax periods include 2009 through 2014.

- Definition

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

+ References+ Details

Employee Benefit Plans

12 Months Ended

Dec. 31, 2014

Employee Benefit Plans [Abstract]

Employee Benefit Plans

Note 8 — Employee Benefit Plans

Defined Contribution Plan

We sponsor a defined contribution 401(k) retirement plan covering substantially all of our employees. Our contributions are in the form of cash and, prior to 2014, consisted of a 50% match of each employee’s contribution up to 5% of the employee’s salary. Beginning in 2014, our matching contributions increased to 75% of the first 5% of the employee’s salary. For the years ended December 31, 2014, 2013 and 2012, our costs related to the 401(k) plan totaled $2.2 million, $1.7 million and $1.6 million, respectively.

Employee Stock Purchase Plan

We have an employee stock purchase plan (the “ESPP”). The ESPP has 1.5 million shares authorized for issuance, of which 1.2 million shares were available for issuance as of December 31, 2014. Eligible employees who participate in the ESPP may purchase shares of our common stock through payroll deductions on an after-tax basis over a four-month period beginning on January 1, May 1, and September 1 of each year during the term of the ESPP, subject to certain restrictions and limitations established by the Compensation Committee of our Board of Directors and Section 423 of the Internal Revenue Code. The per share price of common stock purchased under the ESPP is equal to 85% of the lesser of (i) its fair market value on the first trading day of the purchase period or (ii) its fair market value on the last trading day of the purchase period. The total value of the ESPP awards is calculated using the component approach where each award is computed as the sum of 15% of a share of non-vested stock, a call option on 85% of a share of non-vested stock, and a put option on 15% of a share of non-vested stock. For the years ended December 31, 2014 and 2013, share-based compensation expense with respect to the ESPP was $1.0 million and $0.8 million, respectively.

Long-Term Incentive Stock-Based Plan

We currently have one active long-term incentive stock-based plan, the 2005 Long-Term Incentive Plan, as amended and restated effective May 9, 2012 (the “2005 Incentive Plan”). In May 2012, the shareholders approved an amendment to and restatement of the 2005 Incentive Plan to: (i) authorize 4.3 million additional shares for issuance pursuant to our equity incentive compensation strategy, (ii) authorize incentive stock options, stock appreciation rights, cash awards and performance awards to be made pursuant to the 2005 Incentive Plan, and (iii) include performance criteria for awards that may be made contingent upon the achievement of one or more performance measures, as well as limits on individual awards, in accordance with the requirements for performance-based compensation under Section 162(m) of the Internal Revenue Code. As of December 31, 2014, there were 6.2 million shares available for issuance under the 2005 Incentive Plan, which includes a maximum of 2.0 million shares that may be granted as incentive stock options.

The 2005 Incentive Plan is administered by the Compensation Committee of Helix’s Board of Directors. The Compensation Committee also determines the type of award to be made to each participant and, as set forth in the related award agreement, the terms, conditions and limitations applicable to each award. The Compensation Committee may grant stock options, restricted stock, restricted stock units (“RSUs”), performance share units (“PSUs”) and cash awards. Prior to 2012, awards granted to employees under the incentive plans vested 20% per year over a five-year period. Commencing in 2012, awards granted under the 2005 Incentive Plan have a vesting period of three years (or 33% per year).

The following grants of share-based awards were made in 2014 under the 2005 Incentive Plan:


Date of Grant	Shares		Grant Date Fair Value Per Share	Vesting Period

January 2, 2014 (1)	73,609	$	23.18	33% per year over three years
January 2, 2014 (2)	73,609	$	26.79	100% on January 1, 2017
January 2, 2014 (3)	2,724	$	23.18	100% on January 1, 2016
April 1, 2014 (3)	4,051	$	22.98	100% on January 1, 2016
July 1, 2014 (3)	3,397	$	26.31	100% on January 1, 2016
October 1, 2014 (3)	3,882	$	22.06	100% on January 1, 2016
December 4, 2014 (4)	51,792	$	23.17	33% per year over three years

(1) Reflects the grant of restricted stock to our executive officers.

(2) Reflects the grant of PSUs to our executive officers.

(3) Reflects the grant of restricted stock to certain members of our Board of Directors who have made an election to take their quarterly fees in stock in lieu of cash.

(4) Reflects annual equity grants to each independent member of our Board of Directors.

In January 2015, we granted our executive officers and selected management employees 293,029 shares of restricted stock under the 2005 Incentive Plan. The market value of the restricted shares was $21.67 per share or $6.3 million and the shares vest 33% per year for a three-year period. Separately, we issued our executive officers and selected management employees 293,029 PSUs under the 2005 Incentive Plan.

Compensation cost for restricted stock is the product of grant date fair value of each share and the number of shares granted and is recognized over the respective vesting periods on a straight-line basis. Forfeitures on restricted stock totaled approximately 8% based on our most recent five-year average of historical forfeiture rates. Tax deduction benefits for an award in excess of recognized compensation cost is reported as a financing cash flow rather than as an operating cash flow. Stock-based compensation that is based solely on service conditions is recognized on a straight-line basis over the vesting period of the related shares.

For the years ended December 31, 2014, 2013 and 2012, $10.4 million, $8.8 million, $7.7 million, respectively, was recognized as stock-based compensation expense related to restricted stock, PSUs and RSUs.

Restricted Stock

We grant restricted stock to members of our Board of Directors, executive officers and selected management employees. The following table summarizes information about our restricted stock during the years ended December 31, 2014, 2013 and 2012:


	2014			2013			2012
			Grant Date			Grant Date			Grant Date
	Shares		Fair Value (1)	Shares		Fair Value (1)	Shares		Fair Value (1)

Awards outstanding at beginning of year	771,942	$	13.62	1,191,402	$	14.14	1,263,218	$	14.80
Granted	139,455		23.22	168,468		21.63	349,430		16.30
Vested (2) (3)	(356,437)		11.27	(502,022)		17.50	(400,180)		18.07
Forfeited	-		-	(85,906)		13.79	(21,066)		15.00
Awards outstanding at end of year (3)	554,960	$	17.54	771,942	$	13.62	1,191,402	$	14.14

(1) Represents the weighted average grant date fair value, which is based on the quoted market price of our common stock on the business day prior to the date of grant.

(2) Total fair value of restricted stock and RSUs that vested during the years ended December 31, 2014, 2013 and 2012 was $8.2 million, $11.0 million and $6.7 million, respectively.

(3) The vested and year-end amounts in 2014 each include 33,760 shares of RSUs with the grant date fair value of $15.80 per share. In December 2013, management elected to pay out the January 2014 vesting of these RSUs in cash. As a result, we recorded a $1.3 million liability associated with these RSUs at December 31, 2013 and an additional liability of $0.2 million during 2014. We paid $0.8 million of this liability in January 2014 and $0.7 million in January 2015.

Future compensation expense associated with unvested restricted stock and RSUs at December 31, 2014, 2013, and 2012 totaled approximately $5.7 million, $7.5 million and $11.2 million, respectively. The weighted average vesting period related to unvested restricted stock and RSUs at December 31, 2014 was approximately 1.2 years.

Performance Stock Units

Since 2012, we have issued PSUs to our executive officers. We also issued PSUs to selected management employees in January 2015. The PSUs provide for an award based on the performance of our common stock over a three-year period with the maximum amount of the award being 200% of the original awarded PSUs and the minimum amount being zero. The PSUs vest 100% on the three-year anniversary date of the grant. The vested PSUs may be settled in either cash or shares of our common stock at the discretion of the Compensation Committee of our Board of Directors.

We issued 73,609 PSUs in 2014 with a grant date fair value of $26.79 per unit, 89,329 PSUs in 2013 with a grant date fair value of $27.50 per unit and 132,910 PSUs in 2012 with a grant date fair value of $23.68 per unit. The estimated fair value of the PSUs on grant date was determined using a Monte Carlo simulation model. Until December 2014, the PSUs were being treated as an equity award. Accordingly, compensation expense associated with the PSUs was fixed, as represented by the number of PSUs multiplied by their respective grant date fair value. The fixed amount was being amortized on a straight-line basis over the three-year vesting period. In connection with the vesting of the 2012 PSU awards (which occurred in early January 2015), the decision was made by the Compensation Committee of Helix’s Board of Directors to settle these PSUs with a cash payment rather than an equivalent number of shares of our common stock, which was the default provision of the PSU awards. Accordingly, PSUs are now accounted for as a liability plan. In connection with this determination, we recorded a $7.9 million liability and an additional $3.3 million compensation charge to reflect the estimated fair value of unvested PSUs as of December 31, 2014. We paid $4.5 million of this liability to cash settle the 2012 grant of PSUs when they vested in January 2015.

Stock Options

There have been no stock options granted since 2004. At December 31, 2011, we had 192,800 stock options outstanding at a weighted average exercise price of $10.52 per share. During 2012, 140,000 of these awards were exercised at a weighted average exercise price of $9.24 per share. The remaining 52,800 stock options were exercised in 2013 at a weighted average price of $13.91 per share. There were no stock option awards remaining at December 31, 2013. The aggregate intrinsic value of the stock options exercised during the years ended December 31, 2013 and 2012 was approximately $0.5 million and $1.3 million, respectively. The aggregate intrinsic value of options exercisable at December 31, 2012 was approximately $0.4 million.

Long-Term Incentive Cash Plans

We also have certain long-term incentive cash plans (the “LTI Cash Plans”) that provide long-term cash-based compensation to eligible employees. Cash awards historically have been both fixed sum amounts payable (for non-executive management only) as well as cash awards indexed to our common stock with the payment amount at each vesting date fluctuating based on the performance of our common stock (for both executive and non-executive management). Payment amounts are measured based on the calculated ratio of the average stock price during the applicable measurement period over the original base price determined by the Compensation Committee of our Board of Directors at the time of the award. The maximum amount payable under these share-based cash awards is twice the original targeted award and if the average price during the measurement period is less than 75% of the base price, no payout will be made at the applicable anniversary date. Cash payments under the LTI Cash Plans are made each year on the anniversary date of the award. Cash awards granted since 2012 have a vesting period of three years while those granted prior to 2012 have a vesting period of five years. The LTI Cash Plans are considered liability plans and as such are re-measured to fair value each reporting period with corresponding changes in the liability amount being reflected in our results of operations.

The cash awards granted under the LTI Cash Plans to our executive officers and selected management employees totaled $8.9 million in 2014, $8.4 million in 2013 and $4.2 million in 2012. Total compensation expense associated with the cash awards issued pursuant to the LTI Cash Plans was $7.2 million ($3.6 million related to our executive officers), $9.1 million ($5.3 million related to our executive officers) and $8.7 million ($7.3 million related to our executive officers), respectively, for the years ended December 31, 2014, 2013 and 2012. The liability balance for the cash awards issued under the LTI Cash Plans was $12.8 million at December 31, 2014 and $14.8 million at December 31, 2013, including $7.9 million at December 31, 2014 and $11.1 million at December 31, 2013 associated with the cash awards issued to our executive officers under the LTI Cash Plans. During 2014, 2013 and 2012, we paid $9.2 million, $7.1 million and $5.5 million of the liability associated with the LTI Cash Plans. In January 2015, we paid $8.9 million of the liability balance as of December 31, 2014. No long-term incentive cash awards were granted in January 2015.

- Definition

The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details.

+ References+ Details

Shareholders' Equity

12 Months Ended

Dec. 31, 2014

Shareholders' Equity [Abstract]

Shareholders' Equity

Note 9 — Shareholders’ Equity

Our amended and restated Articles of Incorporation provide for authorized Common Stock of 240,000,000 shares with no stated par value per share and 5,000,000 shares of preferred stock, $0.01 par value per share issuable in one or more series.

The components of Accumulated OCI as of December 31, 2014 and 2013 are as follows (in thousands):


		2014		2013

Cumulative foreign currency translation adjustment	$	(30,161)	$	(10,697)
Unrealized loss on hedges, net (1)		(32,091)		(9,991)
Accumulated other comprehensive loss	$	(62,252)	$	(20,688)

(1)

Amounts relate to foreign currency hedges for the Grand Canyon, the Grand Canyon II and the Grand Canyon III charters as well as interest rate swap contracts for the Term Loan, and are net of deferred income taxes totaling $17.3 million and $5.4 million as of December 31, 2014 and 2013, respectively (Note 15).

- Definition

The entire disclosure for shareholders' equity comprised of portions attributable to the parent entity and noncontrolling interest, including other comprehensive income. Includes, but is not limited to, balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings, accumulated balance for each classification of other comprehensive income and amount of comprehensive income.

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+ Details

Stock Buyback Program	12 Months Ended
Stock Buyback Program	Dec. 31, 2014
Stock Buyback Program [Abstract]
Stock Buyback Program	Note 10 — Stock Buyback Program In June 2009, we announced that we intended to purchase up to 1.5 million shares of our common stock plus an amount equal to additional shares of our common stock granted under our stock-based compensation plans (Note 8) as permitted under our Credit Agreement (Note 6). Our Board of Directors had previously granted us the authority to repurchase shares of our common stock in an amount equal to any equity issued to our employees, officers and directors under our stock-based compensation plans, including share-based awards issued under our existing long-term incentive plans and shares issued to our employees under our employee stock purchase plans (Note 8). We may continue to make repurchases pursuant to this authority from time to time as additional equity is issued under our stock based plans depending on prevailing market conditions and other factors. As described in an announced plan, all repurchases may be commenced or suspended at any time as determined by management. During 2014, we purchased 320,911 shares as then available under this program for $7.7 million or an average of $23.99 per share. As of December 31, 2014, we had repurchased a total of 3,589,425 shares of our common stock for $53.5 million or an average of $14.90 per share. We had 55,674 shares of our common stock available for repurchase under the program at December 31, 2014.

Commitments And Contingencies And Other Matters

12 Months Ended

Dec. 31, 2014

Commitments And Contingencies And Other Matters [Abstract]

Commitments And Contingencies And Other Matters

Note 11 — Commitments and Contingencies and Other Matters

Commitments

Commitments Related to Expansion of Our Fleet

In March 2012, we executed a contract with a shipyard in Singapore for the construction of a newbuild semi-submersible well intervention vessel, the Q5000. This $386.5 million shipyard contract represents the majority of the expected costs associated with the construction of the Q5000. Pursuant to the terms of this contract, payments are made in a fixed percentage of the contract price, together with any variations, on contractually scheduled dates. The vessel is expected to be completed and placed in service in the third quarter of 2015. In September 2014, we entered into the Nordea Credit Agreement to partially finance the construction of the Q5000 and other future capital projects. The Nordea Term Loan will be funded at or near the time of the delivery of the Q5000 (Note 6). At December 31, 2014, our total investment in the Q5000 was $342.4 million, including $289.4 million of scheduled payments made to the shipyard.

In February 2013, we contracted to charter the Grand Canyon II and the Grand Canyon III for use in our robotics operations. The terms of the charters will be five years from the respective delivery dates, both of which are scheduled to be in the first half of 2015.

In September 2013, we executed a second contract with the same shipyard in Singapore that is currently constructing the Q5000. This contract provides for the construction of a newbuild semi-submersible well intervention vessel, the Q7000, which will be built to North Sea standards. This $346.0 million shipyard contract represents the majority of the expected costs associated with the construction of the Q7000. Pursuant to the terms of this contract, 20% of the contract price was paid upon the signing of the contract and the remaining 80% will be paid upon the delivery of the vessel, which is expected to occur in 2016. At December 31, 2014, our total investment in the Q7000 was $91.8 million, including the $69.2 million paid to the shipyard upon signing the contract.

In February 2014, we entered into agreements with Petróleo Brasileiro S.A. (“Petrobras”) to provide well intervention services offshore Brazil. The initial term of the agreements with Petrobras is for four years with options to extend. In connection with the Petrobras agreements, we entered into charter agreements with Siem Offshore AS for two newbuild monohull vessels, both of which are expected to be in service for Petrobras in 2016. At December 31, 2014, our total investment in the topside equipment for the two vessels was $52.0 million. In addition, we paid a charter fee deposit of $12.5 million in November 2014.

Lease Commitments

We lease facilities and charter vessels under non-cancelable operating leases and vessel charters expiring at various dates through 2025. Future minimum rentals at December 31, 2014 are as follows (in thousands):


				Facilities
		Vessels		and Other		Total

2015	$	134,964	$	5,019	$	139,983
2016		159,334		4,570		163,904
2017		160,433		4,391		164,824
2018		126,890		4,418		131,308
2019		122,004		4,478		126,482
Thereafter		282,879		20,714		303,593
Total lease commitments	$	986,504	$	43,590	$	1,030,094

For the years ended December 31, 2014, 2013 and 2012, total rental expense was approximately $147.2 million, $102.1 million and $85.0 million, respectively.

We sublease some of our facilities under non-cancelable sublease agreements. For the years ended December 31, 2014 and 2013, total rental income was $0.8 million and $0.4 million, respectively. As of December 31, 2014, the minimum rentals to be received in the future totaled $2.0 million.

Contingencies and Claims

We believe that there are currently no contingencies which would have a material effect on our financial position, results of operations or cash flows.

Litigation

We are involved in various legal proceedings, primarily involving claims for personal injury under the General Maritime Laws of the United States and the Jones Act based on alleged negligence. In addition, from time to time we incur other claims, such as contract disputes, in the normal course of business.

- Definition

The entire disclosure for commitments and contingencies.

+ References+ Details

Business Segment Information

12 Months Ended

Dec. 31, 2014

Business Segment Information [Abstract]

Business Segment Information

Note 12 — Business Segment Information

We have four reportable business segments: Well Intervention, Robotics, Production Facilities and Subsea Construction. Our Well Intervention segment includes our vessels and equipment used to perform well intervention services primarily in the Gulf of Mexico and North Sea regions. Our well intervention vessels include the Q4000, the Helix 534, the Seawell, the Well Enhancer and the Skandi Constructor, which is a chartered vessel. We are currently constructing two additional well intervention vessels, the Q5000 and the Q7000. We have also contracted to charter two newbuild vessels, which are expected to be delivered in 2016 and used in connection with our contracts to provide well intervention services offshore Brazil. Our Robotics segment currently operates four chartered vessels, and also includes ROVs, trenchers and ROVDrills designed to complement offshore subsea construction and well intervention services. The Production Facilities segment includes the HP I as well as our investments in Deepwater Gateway and Independence Hub that are accounted for under the equity method. Over the past several years, we have sold essentially all of the assets associated with our Subsea Construction business, including the sale in January 2014 of our spoolbase located in Ingleside, Texas (Note 2). As mentioned above, our robotics business provides significant direct services to complement the offshore subsea construction industry, and will continue to do so. All material intercompany transactions between the segments have been eliminated. In February 2013, we sold ERT and as a result, the assets and liabilities included in the sale of ERT and the historical operating results of our former Oil and Gas segment are presented as discontinued operations in the accompanying consolidated financial statements. See Note 13 for additional information regarding our discontinued operations.

We evaluate our performance based on operating income and income before income taxes of each segment. Segment assets are comprised of all assets attributable to each reportable segment. Corporate and other includes all assets not directly identifiable with our business segments. Certain financial data by reportable segment are summarized as follows (in thousands):


		Year Ended December 31,
		2014		2013		2012
Net revenues —
Well Intervention	$	667,849	$	452,452	$	378,546
Robotics		420,224		333,246		328,726
Production Facilities		93,175		88,149		80,091
Subsea Construction		358		71,321		192,521
Intercompany elimination		(74,450)		(68,607)		(133,775)
Total	$	1,107,156	$	876,561	$	846,109

Income (loss) from operations —
Well Intervention	$	204,810	$	131,840	$	85,482
Robotics		68,329		44,132		55,678
Production Facilities		41,138		49,778		40,082
Subsea Construction (1)		10,923		33,685		(148,862)
Corporate and other		(62,523)		(77,041)		(92,985)
Intercompany elimination		(921)		(3,360)		(7,878)
Total	$	261,756	$	179,034	$	(68,483)

Net interest expense and other —
Well Intervention	$	(6,915)	$	(217)	$	2,152
Robotics		7,304		(210)		(1,203)
Production Facilities		384		380		365
Subsea Construction		(278)		480		(247)
Corporate and eliminations (2)		(381)		37,978		64,882
Total	$	114	$	38,411	$	65,949

Equity in earnings of equity investments	$	879	$	2,965	$	8,434


Income (loss) before income taxes —
Well Intervention	$	211,725	$	132,057	$	83,205
Robotics		61,025		44,342		56,881
Production Facilities		41,633		52,363		48,276
Subsea Construction		11,201		33,205		(148,615)
Corporate and eliminations		(63,063)		(118,379)		(165,745)
Total	$	262,521	$	143,588	$	(125,998)

Income tax provision (benefit) —
Well Intervention	$	50,102	$	26,718	$	15,400
Robotics		21,612		15,530		20,222
Production Facilities		14,395		17,233		15,784
Subsea Construction		3,881		11,655		(51,329)
Corporate and eliminations		(23,019)		(39,524)		(59,235)
Total	$	66,971	$	31,612	$	(59,158)


Identifiable assets —
Well Intervention	$	1,470,349	$	1,245,229	$	936,926
Robotics		299,701		282,373		258,117
Production Facilities		459,427		495,829		504,828
Subsea Construction		27,547		38,054		303,479
Corporate and other		443,674		482,795		483,003
Discontinued operations		-		-		900,227
Total	$	2,700,698	$	2,544,280	$	3,386,580

Capital expenditures —
Well Intervention	$	283,635	$	283,132	$	274,451
Robotics		51,348		39,655		44,500
Production Facilities		869		1,252		823
Corporate and other		1,060		387		3,265
Total	$	336,912	$	324,426	$	323,039


Depreciation and amortization —
Well Intervention	$	57,570	$	44,619	$	37,736
Robotics		24,478		22,263		19,933
Production Facilities		21,278		17,193		16,828
Subsea Construction		-		8,651		19,773
Corporate and eliminations		6,019		5,809		2,931
Total	$	109,345	$	98,535	$	97,201

(1) Amount in 2014 includes the $10.5 million gain on the sale of our Ingleside spoolbase in January 2014. Amount in 2013 includes the $1.1 million loss on the sale of the Caesar in June 2013 and the $15.6 million gain on the sale of the Express in July 2013. Amount in 2012 includes impairment charges of $157.8 million for the Caesar and $14.6 million for the Intrepid (Note 2).

(2) Amount in 2014 includes $16.9 million of income with $7.2 million from an insurance reimbursement related to asset retirement work previously performed and the remaining income associated with our overriding royalty interests in ERT’s Wang well, which commenced production in late April 2013.

Intercompany segment amounts are derived primarily from equipment and services provided to other business segments at rates consistent with those charged to third parties. Intercompany segment revenues during the years ended December 31, 2014, 2013 and 2012 are as follows (in thousands):


		Year Ended December 31,
		2014		2013		2012

Well Intervention	$	29,875	$	22,448	$	36,781
Robotics		44,575		41,169		46,465
Production Facilities		-		4,673		46,057
Subsea Construction		-		317		4,472
Total	$	74,450	$	68,607	$	133,775

Intercompany segment profits (losses) (which only relate to intercompany capital projects) during the years ended December 31, 2014, 2013 and 2012 are as follows (in thousands):


		Year Ended December 31,
		2014		2013		2012

Well Intervention	$	(323)	$	(141)	$	6,203
Robotics		1,419		3,518		180
Production Facilities		(175)		(175)		(175)
Subsea Construction		-		158		1,670
Total	$	921	$	3,360	$	7,878

Revenues by individually significant region during the years ended December 31, 2014, 2013 and 2012 are as follows (in thousands):


		Year Ended December 31,
		2014		2013		2012

United States	$	403,994	$	345,525	$	281,308
North Sea (1)		504,016		403,816		345,074
Other		199,146		127,220		219,727
Total	$	1,107,156	$	876,561	$	846,109

(1) Includes revenues of $362.7 million, $327.1 million and $283.1 million, respectively, which were from the United Kingdom during years ended December 31, 2014, 2013 and 2012.

We include the property and equipment, net in the geographic country in which it legally resides. The following table provides our property and equipment, net of accumulated depreciation, by individually significant region (in thousands):


		Year Ended December 31,
		2014		2013		2012

United States	$	913,422	$	1,119,075	$	1,180,586
United Kingdom		355,996		336,317		304,062
Luxembourg		465,875		76,749		-
Other		91		76		1,227
Total	$	1,735,384	$	1,532,217	$	1,485,875

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

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+ Details

Oil And Gas Properties

12 Months Ended

Dec. 31, 2014

Oil And Gas Properties [Abstract]

Oil And Gas Properties

Note 13 — Oil and Gas Properties

Results of Discontinued Operations

In February 2013, we sold ERT for $624 million plus additional consideration in the form of overriding royalty interests in ERT’s Wang well and certain exploration prospects. As a result, we have presented the historical operating results of our former Oil and Gas segment as discontinued operations in the accompanying consolidated financial statements.

The following summarized financial information relates to ERT, which is reported as “Income (loss) from discontinued operations, net of tax” in the accompanying consolidated statements of operations (in thousands):


		Year Ended December 31,
		2013 (1)		2012

Revenues	$	48,847	$	557,231
Costs:
Production (lifting) costs		16,017		164,663
Hurricane repair expense		-		662
Exploration expenses		3,514		3,295
Depreciation, depletion, amortization and accretion		1,226		158,284
Proved property impairment and abandonment (2)		(152)		151,045
Loss on sale of oil and gas properties		-		1,714
Hedge ineffectiveness and non-hedge gain on commodity derivative contracts		-		(5,550)
Selling, general and administrative expenses		1,229		17,823
Net interest expense and other (3)		2,732		28,191
Total costs		24,566		520,127
Pretax income from discontinued operations		24,281		37,104
Income tax provision		8,499		13,420
Income from operations of discontinued operations		15,782		23,684
Loss on sale of business, net of tax		(14,709)		-
Income from discontinued operations, net of tax	$	1,073	$	23,684

(1) Results for 2013 reflect the operating results from January 1, 2013 through February 6, 2013 when ERT was sold. There were no material results of operations for our former oil and gas segment subsequent to the sale of ERT.

(2) Results for 2012 include a charge of $138.6 million to reduce our carrying amount of ERT to its estimated fair value less costs to sell.

(3) Net interest expense of $2.7 million and $27.7 million, respectively, for the years ended December 31, 2013 and 2012 was allocated to ERT and primarily consisted of interest associated with indebtedness directly attributed to the substantial oil and gas acquisition made in 2006. This includes interest related to debt required to be repaid upon the disposition of ERT.

Revenue Recognition for Royalty Interests

Revenues from royalty interests are recognized according to monthly oil and gas production on an entitlement basis. Revenues for royalty interests are reflected in “Other income – oil and gas” in the accompanying consolidated statements of operations.

United Kingdom Property

Since 2006, we have maintained an ownership interest in the Camelot field, located offshore in the North Sea. This property was not included in the sale of ERT. Modifications to U.K. regulations governing such operations required us to reassess our existing abandonment plan and cost estimates in 2011. The results of this review concluded that the scope of work to be performed in the abandoning of the wells in the field would be significantly expanded and as a result our cost estimates significantly increased. Based on our abandonment plan in accordance with applicable regulations in the United Kingdom, we recorded $15.5 million of additional charges to expense in 2012 to reflect increases in our estimated costs to complete our abandonment activities at Camelot, including the removal of certain environmentally sensitive materials. At December 31, 2012, the recorded asset retirement obligation for the Camelot field was $2.9 million.

During 2013, we recorded a $1.6 million charge reflecting the estimated final costs to complete the abandonment of Camelot. We completed our reclamation activities for this offshore property in 2013, including removing and appropriately disposing of all the related structures, and the plugging and abandoning of all the wells associated with the property. At December 31, 2014 and 2013, the remaining asset retirement obligation related to the regulatory compliance process was $0.6 million and $1.1 million, respectively.

The operating results and financial position associated with our U.K. property did not qualify for discontinued operations accounting treatment as this property was not classified as held for sale, and thus are reflected as continuing operations in our consolidated financial statements for all periods presented. Other than the impairment charges and asset retirement costs described above, the operating results associated with the Camelot field were immaterial for all periods presented in this Annual Report.

Separately, we retained the reclamation obligations associated with one property located in the Gulf of Mexico pursuant to the terms of the ERT sale transaction. During 2013, we paid $5.2 million for our pro-rata share of the costs to complete the reclamation of this property. For the year ended December 31, 2014, we recorded a $7.2 million insurance reimbursement related to asset retirement work previously performed on this property.

Allowance Accounts

12 Months Ended

Dec. 31, 2014

Allowance Accounts [Abstract]

Allowance Accounts

Note 14 — Allowance Accounts

The following table sets forth the activity in our valuation accounts for each of the three years in the period ended December 31, 2014 (in thousands):


		Allowance		Deferred
		for		Tax Asset
		Uncollectible		Valuation
		Accounts		Allowance

Balance at December 31, 2011	$	4,000	$	14,310
Additions (1)		1,257		2,081
Deductions		(105)		-
Balance at December 31, 2012		5,152		16,391
Additions (2)		2,236		6,469
Deductions (3)		(5,154)		-
Balance at December 31, 2013	$	2,234	$	22,860
Additions (4)		5,331		216
Deductions (5)		(2,830)		-
Balance at December 31, 2014	$	4,735	$	23,076

(1) The increase in valuation allowance includes $2.0 million related to our net operating losses generated in Australia and $0.1 million to our oil and gas operations in the United Kingdom. Our Australia deferred tax asset balance has a full valuation allowance against it in all periods presented.

(2) The increase in valuation allowance includes $6.5 million related to our net operating losses generated in Australia.

(3) The decrease primarily reflects the reversal of a $4 million allowance against our trade receivables for work performed offshore India in 2007 as we collected the previously adjusted receivable balance pursuant to a settlement agreement.

(4) The increase in allowance for uncollectible accounts reflects charges associated with the provision for uncertain collection of a portion of our existing trade receivables related to our Robotics segment.

(5) The decrease reflects the write-offs of trade receivables deemed uncollectible.

See Note 2 for a detailed discussion regarding our accounting policy on accounts receivable and allowance for uncollectible accounts and Note 7 for a detailed discussion of the valuation allowance related to our deferred tax assets.

Derivative Instruments And Hedging Activities

12 Months Ended

Dec. 31, 2014

Derivative Instruments And Hedging Activities [Abstract]

Derivative Instruments And Hedging Activities

Note 15 — Derivative Instruments and Hedging Activities

Derivatives designated as hedging instruments are as follows (in thousands):


	As of December 31, 2014			As of December 31, 2013
	Balance Sheet		Fair	Balance Sheet		Fair
	Location		Value	Location		Value
Asset Derivatives:
Interest rate swaps	Other assets, net	$	369	Other assets, net	$	446
		$	369		$	446

Liability Derivatives:
Foreign exchange contracts	Accrued liabilities	$	12,661	Accrued liabilities	$	1,905
Interest rate swaps	Accrued liabilities		561	Accrued liabilities		746
Foreign exchange contracts	Other non-current liabilities		37,767	Other non-current liabilities		13,166
		$	50,989		$	15,817

Derivatives that were not designated as hedging instruments are as follows (in thousands):


	As of December 31, 2014			As of December 31, 2013
	Balance Sheet		Fair	Balance Sheet		Fair
	Location		Value	Location		Value
Asset Derivatives:
Foreign exchange contracts	Other current assets	$	-	Other current assets	$	69
		$	-		$	69

As a result of the announcement in December 2012 of the sale of ERT, we de-designated all of our then remaining oil and gas derivative contracts as hedging instruments. In addition, under the terms of our former credit facility (Note 6), we were required to use a portion of the proceeds from the sale of ERT as well as from the sale of the Caesar and Express vessels, to make payments to reduce our indebtedness. Because of the probability that the former term loan debt would be totally repaid before the expiration of our then existing interest rate swaps, we also concluded in December 2012 that those swaps no longer qualified as cash flow hedges. In connection with the de-designation of these derivative contracts as hedging instruments, we were required to recognize amounts previously recorded in Accumulated OCI and related deferred taxes into earnings. The mark-to-market adjustments related to our oil and gas commodity derivative contracts and interest rate swaps are reflected in “Loss on commodity derivative contracts” and “Other income (expense), net”, respectively, in the accompanying consolidated statements of operations. In February 2013, we settled all of our then remaining commodity derivative contracts and then existing interest rate swap contracts for payments of approximately $22.5 million and $0.6 million, respectively.

In January 2013, we entered into foreign currency exchange contracts to hedge through September 2017 the foreign currency exposure associated with the Grand Canyon charter payments ($104.6 million) denominated in Norwegian kroner (NOK591.3 million). In February 2013, we entered into similar foreign currency exchange contracts to hedge our foreign currency exposure with respect to the Grand Canyon II and Grand Canyon III charter payments ($100.4 million and $98.8 million, respectively) denominated in Norwegian kroner (NOK594.7 million and NOK595.0 million, respectively), through July 2019 and February 2020, respectively. These contracts currently qualify for hedge accounting treatment. All of our remaining foreign exchange contracts that were not accounted for as hedge contracts have been settled. We had no foreign currency exchange contracts for vessel charters denominated in British pounds as of December 31, 2014.

In September 2013, we entered into various interest rate swap contracts to fix the interest rate on $148.1 million of our Term Loan debt (Note 6). These monthly contracts began in October 2013 and extend through October 2016. These contracts are accounted for under hedge accounting.

For the year ended December 31, 2014, we recorded losses totaling $1.7 million in “Other income (expense), net” in the accompanying consolidated statement of operations related to ineffectiveness associated with our foreign currency hedges with respect to the Grand Canyon II charter payments. Ineffectiveness associated with our cash flow hedges was immaterial for the years ended December 31, 2013 and 2012. The following tables present the impact that derivative instruments designated as cash flow hedges had on our Accumulated OCI (net of tax) and our consolidated statements of operations for the years ended December 31, 2014, 2013 and 2012 (in thousands). We estimate that as of December 31, 2014, $7.8 million of losses in Accumulated OCI associated with our derivatives is expected to be reclassified into earnings within the next 12 months.


		Gain (Loss) Recognized in OCI
		on Derivatives, Net of Tax
		(Effective Portion)
		Year Ended December 31,
		2014		2013		2012

Foreign exchange contracts	$	(22,170)	$	(9,796)	$	-
Oil and gas commodity contracts		-		-		(12,860)
Interest rate swaps		70		(195)		(81)
	$	(22,100)	$	(9,991)	$	(12,941)


			Gain (Loss) Reclassified from
	Location of Gain (Loss)		Accumulated OCI into Earnings
	Reclassified from		(Effective Portion)
	Accumulated OCI into Earnings		Year Ended December 31,
	(Effective Portion)		2014		2013		2012

Oil and gas commodity contracts	Income from discontinued operations, net of tax	$	-	$	-	$	3,184
Interest rate swaps	Net interest expense		(858)		(152)		(523)
Foreign exchange contracts	Cost of sales		(2,507)		(1,324)		-
		$	(3,365)	$	(1,476)	$	2,661

The following table presents the impact that derivative instruments not designated as hedges had on our consolidated statement of operations for the years ended December 31, 2014, 2013 and 2012 (in thousands):


			Gain (Loss) Recognized
	Location of Gain (Loss)		in Earnings on Derivatives
	Recognized in Earnings		Year Ended December 31,
	on Derivatives		2014		2013		2012

Oil and gas commodity contracts	Income from discontinued operations, net of tax	$	-	$	-	$	5,550
Oil and gas commodity contracts	Loss on commodity derivative contracts		-		(14,113)		(10,507)
Interest rate swaps	Other expense, net		-		(86)		(567)
Foreign exchange contracts	Other expense, net		7		(630)		411
		$	7	$	(14,829)	$	(5,113)

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

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+ Details

Quarterly Financial Information

12 Months Ended

Dec. 31, 2014

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Information

Note 16 — Quarterly Financial Information (Unaudited)

Offshore marine construction activities may fluctuate as a result of weather conditions and the timing of capital expenditures by oil and gas companies. Historically, a substantial portion of our services has been performed during the summer and fall months. As a result, historically a disproportionate portion of our revenues and net income is earned during such period. The following is a summary of consolidated quarterly financial information for 2014 and 2013 (in thousands, except per share amounts):


		Quarter Ended
		March 31,		June 30,		September 30,		December 31,
2014
Net revenues	$	253,572	$	305,587	$	340,837	$	207,160
Gross profit	$	75,846	$	109,138	$	126,247	$	32,805
Net income applicable to Helix	$	53,719	$	57,782	$	75,586	$	7,960
Basic earnings per common share	$	0.51	$	0.55	$	0.72	$	0.08
Diluted earnings per common share	$	0.51	$	0.55	$	0.71	$	0.08


		Quarter Ended
		March 31,		June 30,		September 30,		December 31,
2013
Net revenues (1)	$	197,429	$	232,178	$	220,117	$	226,837
Gross profit (2)		52,567		67,497		69,457		71,164
Net income applicable to Helix:
Income from continuing operations	$	557	$	27,240	$	44,549	$	36,503
Income (loss) from discontinued operations		1,058		(29)		44		-
Net income applicable to Helix	$	1,615	$	27,211	$	44,593	$	36,503
Basic earnings per common share:
Income from continuing operations	$	0.01	$	0.26	$	0.42	$	0.35
Income from discontinued operations		0.01		-		-		-
Basic earnings per common share	$	0.02	$	0.26	$	0.42	$	0.35
Diluted earnings per common share:
Income from continuing operations	$	0.01	$	0.26	$	0.42	$	0.35
Income from discontinued operations		0.01		-		-		-
Diluted earnings per common share	$	0.02	$	0.26	$	0.42	$	0.35

(1) Excludes revenues from discontinued operations of $48.8 million for the quarter ended March 31, 2013.

(2) Excludes gross profit from discontinued operations of $28.2 million for the quarter ended March 31, 2013.

- Definition

The entire disclosure for the quarterly financial data in the annual financial statements. The disclosure may include a tabular presentation of financial information for each fiscal quarter for the current and previous year, including revenues, gross profit, income or loss before extraordinary items and earnings per share data. It also includes an indication if the information in the note is unaudited, comments on the aggregate effect of year-end adjustments, and an explanation of matters or transactions that affect comparability or are pertinent to an understanding of the information furnished.

+ References+ Details

Summary Of Significant Accounting Policies (Policy)

12 Months Ended

Dec. 31, 2014

Summary Of Significant Accounting Policies [Abstract]

Principles Of Consolidation

Principles of Consolidation

Use Of Estimates

Use of Estimates

Cash And Cash Equivalents

Cash and Cash Equivalents

Cash and cash equivalents are highly liquid financial instruments with original maturities of three months or less. They are carried at cost plus accrued interest, which approximates fair value.

Statement Of Cash Flow Information

Statement of Cash Flow Information

The following table provides supplemental cash flow information for the periods stated (in thousands):


		Year Ended December 31,
		2014		2013		2012

Interest paid, net of interest capitalized	$	11,628	$	39,040	$	68,735
Income taxes paid	$	70,509	$	113,331	$	43,111

Accounts and Notes Receivable and Allowance for Uncollectible Accounts

Property And Equipment

Property and Equipment


	Estimated Useful Life		2014		2013

Vessels	15 to 30 years	$	1,657,448	$	1,403,573
ROVs, trenchers and ROVDrills	10 years		310,841		271,801
Machinery, equipment, buildings and leasehold improvements	5 to 30 years		273,155		288,332
Total property and equipment		$	2,241,444	$	1,963,706

Equity Investments

Goodwill

The changes in the carrying amount of goodwill are as follows (in thousands):


		Well
		Intervention		Robotics		Total

Balance at December 31, 2012	$	17,828	$	45,107	$	62,935
Other adjustments (1)		295		-		295
Balance at December 31, 2013		18,123		45,107		63,230
Other adjustments (1)		(1,084)		-		(1,084)
Balance at December 31, 2014	$	17,039	$	45,107	$	62,146

(1)

Reflects foreign currency adjustment for certain amounts of our goodwill.

Recertification Costs And Deferred Dry Dock Charges

Recertification Costs and Deferred Dry Dock Charges

Revenue Recognition

	•		the customer provides specifications for the provision of services;
	•		we can reasonably estimate our progress towards completion and our costs;
	•		the contract includes provisions for the enforceable rights regarding the goods or services to be provided, consideration to be received, and the manner and terms of payment;
	•		the customer can be expected to satisfy its obligations under the contract; and
	•		we can be expected to perform our contractual obligations.

Income Taxes

Foreign Currency

Derivative Instruments And Hedging Activities

Derivative Instruments and Hedging Activities

Interest Rate Risk

Foreign Currency Exchange Rate Risk

See Note 15 for more information regarding the accounting for our derivative contracts including our oil and gas commodity contracts associated with ERT.

Earnings Per Share


		Year Ended December 31,
		2014			2013			2012
		Income	Shares		Income	Shares		Income	Shares
Basic:
Continuing operations:
Net income applicable to Helix	$	195,047		$	109,922		$	(46,334)
Less: Income from discontinued operations, net of tax		-			(1,073)			(23,684)
Net income from continuing operations		195,047			108,849			(70,018)
Less: Undistributed income allocable to participating securities – continuing operations		(1,018)			(801)			-
Net income applicable to common shareholders – continuing operations	$	194,029	105,029	$	108,048	105,032	$	(70,018)	104,449


Discontinued operations:
Income from discontinued operations, net of tax	$	-		$	1,073		$	23,684
Less: Undistributed income allocable to participating securities – discontinued operations		-			(8)			-
Net income applicable to common shareholders – discontinued operations	$	-	105,029	$	1,065	105,032	$	23,684	104,449


		Year Ended December 31,
		2014			2013			2012
		Income	Shares		Income	Shares		Income	Shares
Diluted:
Continuing operations:
Net income applicable to common shareholders – continuing operations	$	194,029	105,029	$	108,048	105,032	$	(70,018)	104,449
Effect of dilutive securities:
Share-based awards other than participating securities		-	16		-	152		-	-
Undistributed income reallocated to participating securities		-	-		1	-		-	-
Net income applicable to common shareholders – continuing operations	$	194,029	105,045	$	108,049	105,184	$	(70,018)	104,449

Discontinued operations:
Income from discontinued operations, net of tax	$	-	105,045	$	1,073	105,184	$	23,684	104,449


		2012

Diluted shares (as reported)		104,449
Share-based awards		382
Convertible preferred stock		334
Total		105,165

Major Customers And Concentration Of Credit Risk

Major Customers and Concentration of Credit Risk

Fair Value Measurements


	•		Level 1. Observable inputs such as quoted prices in active markets;
	•		Level 2. Inputs, other than the quoted prices in active markets, that are observable either directly or indirectly; and
	•		Level 3. Unobservable inputs for which there is little or no market data, which require the reporting entity to develop its own assumptions.

Assets and liabilities measured at fair value are based on one or more of three valuation techniques as follows:

(a)

Market Approach. Prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities.

(b)

Cost Approach. Amount that would be required to replace the service capacity of an asset (replacement cost).

(c)


		Fair Value Measurements at
		December 31, 2014 Using							Valuation
		Level 1		Level 2 (1)		Level 3		Total	Technique
Assets:
Interest rate swaps	$	-	$	369	$	-	$	369	(c)

Liabilities:
Fair value of long-term debt (2)		222,900		375,393		-		598,293	(a)
Foreign exchange contracts		-		50,428		-		50,428	(c)
Interest rate swaps		-		561		-		561	(c)
Total net liability	$	222,900	$	426,013	$	-	$	648,913


		Fair Value Measurements at
		December 31, 2013 Using							Valuation
		Level 1		Level 2 (1)		Level 3		Total	Technique
Assets:
Foreign exchange contracts	$	-	$	69	$	-	$	69	(c)
Interest rate swaps		-		446		-		446	(c)

Liabilities:
Fair value of long-term debt (2)		242,250		403,437		-		645,687	(a)
Foreign exchange contracts		-		15,071		-		15,071	(c)
Interest rate swaps		-		746		-		746	(c)
Total net liability	$	242,250	$	418,739	$	-	$	660,989

(2) See Note 6 for additional information regarding our long-term debt. The value of our long-term debt at December 31, 2014 and 2013 is as follows (in thousands):


		2014				2013
		Carrying		Fair		Carrying		Fair
		Amount		Value (b)		Amount		Value (b)

Term Loan (matures June 2018)	$	277,500	$	270,563	$	292,500	$	293,963
2032 Notes (mature March 2032) (a)		200,000		222,900		200,000		242,250
MARAD Debt (matures February 2027)		94,792		104,830		100,168		109,474
Total debt	$	572,292	$	598,293	$	592,668	$	645,687

(a) Carrying amount excludes the related unamortized debt discount of $20.9 million and $26.5 million at December 31, 2014 and 2013, respectively.

Debt Discount

Convertible Preferred Stock

Related Party Transactions

New Accounting Standards

We do not expect any other recent accounting standards to have a material impact on our financial position, results of operations or cash flows.

Summary Of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2014

Summary Of Significant Accounting Policies [Abstract]

Supplemental Cash Flow Information


		Year Ended December 31,
		2014		2013		2012

Interest paid, net of interest capitalized	$	11,628	$	39,040	$	68,735
Income taxes paid	$	70,509	$	113,331	$	43,111

Property, Plant And Equipment


	Estimated Useful Life		2014		2013

Vessels	15 to 30 years	$	1,657,448	$	1,403,573
ROVs, trenchers and ROVDrills	10 years		310,841		271,801
Machinery, equipment, buildings and leasehold improvements	5 to 30 years		273,155		288,332
Total property and equipment		$	2,241,444	$	1,963,706

Schedule Of Goodwill


		Well
		Intervention		Robotics		Total

Balance at December 31, 2012	$	17,828	$	45,107	$	62,935
Other adjustments (1)		295		-		295
Balance at December 31, 2013		18,123		45,107		63,230
Other adjustments (1)		(1,084)		-		(1,084)
Balance at December 31, 2014	$	17,039	$	45,107	$	62,146

(1)

Reflects foreign currency adjustment for certain amounts of our goodwill.

Computations Of Basic And Diluted EPS


		Year Ended December 31,
		2014			2013			2012
		Income	Shares		Income	Shares		Income	Shares
Basic:
Continuing operations:
Net income applicable to Helix	$	195,047		$	109,922		$	(46,334)
Less: Income from discontinued operations, net of tax		-			(1,073)			(23,684)
Net income from continuing operations		195,047			108,849			(70,018)
Less: Undistributed income allocable to participating securities – continuing operations		(1,018)			(801)			-
Net income applicable to common shareholders – continuing operations	$	194,029	105,029	$	108,048	105,032	$	(70,018)	104,449


Discontinued operations:
Income from discontinued operations, net of tax	$	-		$	1,073		$	23,684
Less: Undistributed income allocable to participating securities – discontinued operations		-			(8)			-
Net income applicable to common shareholders – discontinued operations	$	-	105,029	$	1,065	105,032	$	23,684	104,449


		Year Ended December 31,
		2014			2013			2012
		Income	Shares		Income	Shares		Income	Shares
Diluted:
Continuing operations:
Net income applicable to common shareholders – continuing operations	$	194,029	105,029	$	108,048	105,032	$	(70,018)	104,449
Effect of dilutive securities:
Share-based awards other than participating securities		-	16		-	152		-	-
Undistributed income reallocated to participating securities		-	-		1	-		-	-
Net income applicable to common shareholders – continuing operations	$	194,029	105,045	$	108,049	105,184	$	(70,018)	104,449

Discontinued operations:
Income from discontinued operations, net of tax	$	-	105,045	$	1,073	105,184	$	23,684	104,449

Excluded Securities On Diluted Shares Calculation


		2012

Diluted shares (as reported)		104,449
Share-based awards		382
Convertible preferred stock		334
Total		105,165

Assets And Liabilities Measured At Fair Value On A Recurring Basis


		Fair Value Measurements at
		December 31, 2014 Using							Valuation
		Level 1		Level 2 (1)		Level 3		Total	Technique
Assets:
Interest rate swaps	$	-	$	369	$	-	$	369	(c)

Liabilities:
Fair value of long-term debt (2)		222,900		375,393		-		598,293	(a)
Foreign exchange contracts		-		50,428		-		50,428	(c)
Interest rate swaps		-		561		-		561	(c)
Total net liability	$	222,900	$	426,013	$	-	$	648,913


		Fair Value Measurements at
		December 31, 2013 Using							Valuation
		Level 1		Level 2 (1)		Level 3		Total	Technique
Assets:
Foreign exchange contracts	$	-	$	69	$	-	$	69	(c)
Interest rate swaps		-		446		-		446	(c)

Liabilities:
Fair value of long-term debt (2)		242,250		403,437		-		645,687	(a)
Foreign exchange contracts		-		15,071		-		15,071	(c)
Interest rate swaps		-		746		-		746	(c)
Total net liability	$	242,250	$	418,739	$	-	$	660,989

(2) See Note 6 for additional information regarding our long-term debt. The value of our long-term debt at December 31, 2014 and 2013 is as follows (in thousands):

Value Of Long Term Debt


		2014				2013
		Carrying		Fair		Carrying		Fair
		Amount		Value (b)		Amount		Value (b)

Term Loan (matures June 2018)	$	277,500	$	270,563	$	292,500	$	293,963
2032 Notes (mature March 2032) (a)		200,000		222,900		200,000		242,250
MARAD Debt (matures February 2027)		94,792		104,830		100,168		109,474
Total debt	$	572,292	$	598,293	$	592,668	$	645,687

(a) Carrying amount excludes the related unamortized debt discount of $20.9 million and $26.5 million at December 31, 2014 and 2013, respectively.

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 235

-SubTopic 10

-Section S99

-Paragraph 1

-Subparagraph (SX 210.4-08.(e),(f))

-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 835

-SubTopic 30

-Section 55

-Paragraph 8

-URI http://asc.fasb.org/extlink&oid=34725769&loc=d3e28878-108400

Reference 3: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

-Topic 835

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-Section 45

-Paragraph 2

-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28551-108399

Reference 4: http://www.xbrl.org/2003/role/presentationRef

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Reference 5: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

-Topic 505

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-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 210

-SubTopic 10

-Section S99

-Paragraph 1

-Subparagraph (SX 210.5-02.22)

-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 02

-Paragraph 22

-Article 5

Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 505

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-Paragraph 6

-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 9: http://www.xbrl.org/2003/role/presentationRef

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Reference 10: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

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-Name Accounting Standards Codification

-Topic 942

-SubTopic 470

-Section 50

-Paragraph 3

-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

+ Details

Details Of Certain Accounts (Tables)

12 Months Ended

Dec. 31, 2014

Details Of Certain Accounts [Abstract]

Schedule Of Other Current Assets


		2014		2013

Note receivable (1)	$	17,500	$	-
Other receivables		423		785
Prepaid insurance		6,582		7,038
Other prepaids		15,541		12,999
Spare parts inventory		1,857		1,038
Value added tax receivable		9,326		7,589
Other		72		260
Total other current assets	$	51,301	$	29,709

(1)

Relates to the remaining balance of the promissory note we received in connection with the sale of our Ingleside spoolbase in January 2014 (Note 2)

Schedule Of Other Assets, Net


		2014		2013

Note receivable (1)	$	10,000	$	-
Deferred dry dock expenses, net (Note 2)		11,631		20,833
Deferred financing costs, net (Note 6)		23,399		24,297
Intangible assets with finite lives, net		696		622
Charter fee deposit (Note 11)		12,544		-
Other		1,002		1,515
Total other assets, net	$	59,272	$	47,267

(1)

Relates to the remaining balance of the promissory note we received in connection with the sale of our Ingleside spoolbase in January 2014 (Note 2).

Schedule Of Accrued Liabilities


		2014		2013

Accrued payroll and related benefits	$	61,246	$	50,527
Current asset retirement obligations		575		2,024
Unearned revenue		11,461		19,608
Billing in excess of cost		-		1,677
Accrued interest		4,221		4,187
Derivative liability (Note 15)		13,222		2,651
Taxes payable excluding income tax payable		6,236		4,811
Pipelay assets sale deposit		-		5,000
Other		7,962		5,997
Total accrued liabilities	$	104,923	$	96,482

Equity Investments (Tables)

12 Months Ended

Dec. 31, 2014

Equity Investments [Abstract]

Distributions From Equity Investments


		Year Ended December 31,
		2014		2013		2012

Deepwater Gateway	$	6,150	$	7,600	$	8,157
Independence Hub		2,640		4,660		8,073
Total	$	8,790	$	12,260	$	16,230

Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2014

Long-Term Debt [Abstract]

Schedule Of Debt


		2014		2013

Term Loan (matures June 2018)	$	277,500	$	292,500
2032 Notes (mature March 2032)		200,000		200,000
MARAD Debt (matures February 2027)		94,792		100,168
Unamoritized debt discount		(20,920)		(26,516)
Total debt		551,372		566,152
Less current maturities		(28,144)		(20,376)
Long-term debt	$	523,228	$	545,776

Schedule Of Deferred Financing Costs


		December 31, 2014						December 31, 2013
		Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net

Term Loan (matures June 2018) (1)	$	3,638	$	(1,091)	$	2,547	$	3,638	$	(364)	$	3,274
Revolving Credit Facility (matures June 2018) (1)		13,275		(3,982)		9,293		13,275		(1,327)		11,948
2032 Notes (mature March 2032)		3,759		(1,763)		1,996		3,759		(1,148)		2,611
MARAD Debt (matures February 2027)		12,200		(6,223)		5,977		12,200		(5,736)		6,464
Nordea Term Loan		3,586		-		3,586		-		-		-
Total deferred financing costs	$	36,458	$	(13,059)	$	23,399	$	32,872	$	(8,575)	$	24,297

(1) Relates to amounts allocated to the existing Term Loan and Revolving Credit Facility, which became effective in June 2013.

Schedule Of Maturities Of Long-Term Debt


		Term Loan		MARAD Debt		2032 Notes (1)		Total

Less than one year	$	22,500	$	5,644	$	-	$	28,144
One to two years		30,000		5,926		-		35,926
Two to three years		30,000		6,222		-		36,222
Three to four years		195,000		6,532		-		201,532
Four to five years		-		6,858		-		6,858
Over five years		-		63,610		200,000		263,610
Total debt		277,500		94,792		200,000		572,292
Current maturities		(22,500)		(5,644)		-		(28,144)
Long-term debt, less current maturities		255,000		89,148		200,000		544,148
Unamortized debt discount (2)		-		-		(20,920)		(20,920)
Long-term debt	$	255,000	$	89,148	$	179,080	$	523,228

(1) Beginning in March 2018, the holders of the 2032 Notes may require us to repurchase these notes or we may at our option elect to repurchase these notes. The notes will mature in March 2032.

(2) The 2032 Notes will increase to their face amount through accretion of non-cash interest charges through March 2018.

Schedule Of Components of Net Interest Expense


		Year Ended December 31,
		2014		2013		2012

Interest expense (1)	$	33,064	$	44,484	$	53,601
Interest income		(4,786)		(1,167)		(548)
Capitalized interest		(10,419)		(10,419)		(4,893)
Net interest expense	$	17,859	$	32,898	$	48,160

(1)

Income Taxes (Tables)

12 Months Ended

Dec. 31, 2014

Income Taxes [Abstract]

Schedule of Components of Income Tax Expense (Benefit)


		Year Ended December 31,
		2014		2013		2012

Current	$	43,817	$	57,128	$	6,572
Deferred		23,154		(25,516)		(65,730)
	$	66,971	$	31,612	$	(59,158)


Domestic	$	29,613	$	11,615	$	(78,211)
Foreign		37,358		19,997		19,053
	$	66,971	$	31,612	$	(59,158)

Schedule of Components of Income (Loss) Before Income Taxes


		Year Ended December 31,
		2014		2013		2012

Domestic	$	73,700	$	36,176	$	(256,859)
Foreign		188,821		107,412		130,861
	$	262,521	$	143,588	$	(125,998)

Schedule Of Effective Income Tax Rate Reconciliation


	Year Ended December 31,
	2014		2013		2012

Statutory rate	35.0	%	35.0	%	35.0	%
Foreign provision	(9.1)		(11.6)		11.2
Other	(0.4)		(1.4)		0.8
Effective rate	25.5	%	22.0	%	47.0	%

Schedule of Deferred Tax Assets and Liabilities


		2014		2013
Deferred tax liabilities:
Depreciation	$	211,903	$	169,404
Original Issue Discount on 2032 Notes		16,269		14,720
Equity investments in production facilities		50,685		84,870
Prepaid and other		4,211		7,556
Total deferred tax liabilities	$	283,068	$	276,550

Deferred tax assets:
Net operating losses	$	(23,076)	$	(40,105)
Reserves, accrued liabilities and other		(53,973)		(44,999)
Total deferred tax assets		(77,049)		(85,104)
Valuation allowance		23,076		22,860

Net deferred tax liabilities	$	229,095	$	214,306

Deferred income tax is presented as:
Current deferred tax assets		(31,180)		(51,573)
Noncurrent deferred tax liabilities		260,275		265,879
Net deferred tax liabilities	$	229,095	$	214,306

Reconciliation of Beginning and Ending Amount of Unrecognized Tax Benefits


		2014		2013		2012

Balance at January 1,	$	4,723	$	4,506	$	7,085
Additions for tax positions of prior years		-		217		206
Reductions for tax positions of prior years		(4,723)		-		(2,785)
Balance at December 31,	$	-	$	4,723	$	4,506

- Definition

Tabular disclosure of tax positions taken in the tax returns filed or to be filed for which it is more likely than not that the tax position will not be sustained upon examination by taxing authorities (i.e., uncertain tax positions) and other types of income tax contingencies, including: (1) the policy on classification of interest and penalties; (2) a tabular reconciliation of the total amounts of unrecognized tax benefits at the beginning and end of the period; the total amount(s) of: (3) unrecognized tax benefits that, if recognized, would affect the effective tax rate, and (4) interest and penalties recognized in each of the income statement and balance sheet; (5) for positions for which it is reasonably possible that the total amounts unrecognized will significantly change within 12 months of the reporting date the: (i) nature of the uncertainty, (ii) nature of the event that could occur that would cause the change, and (iii) an estimate of the range of the reasonably possible change or a statement that an estimate of the range cannot be made; and (6) a description of tax years that remain subject to examination by major tax jurisdictions.

+ References+ Details

Employee Benefit Plans (Tables)

12 Months Ended

Dec. 31, 2014

Employee Benefit Plans [Abstract]

Schedule Of Share-based Awards

Date of Grant	Shares		Grant Date Fair Value Per Share	Vesting Period

January 2, 2014 (1)	73,609	$	23.18	33% per year over three years
January 2, 2014 (2)	73,609	$	26.79	100% on January 1, 2017
January 2, 2014 (3)	2,724	$	23.18	100% on January 1, 2016
April 1, 2014 (3)	4,051	$	22.98	100% on January 1, 2016
July 1, 2014 (3)	3,397	$	26.31	100% on January 1, 2016
October 1, 2014 (3)	3,882	$	22.06	100% on January 1, 2016
December 4, 2014 (4)	51,792	$	23.17	33% per year over three years

(1) Reflects the grant of restricted stock to our executive officers.

(2) Reflects the grant of PSUs to our executive officers.

(3) Reflects the grant of restricted stock to certain members of our Board of Directors who have made an election to take their quarterly fees in stock in lieu of cash.

(4) Reflects annual equity grants to each independent member of our Board of Directors.

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity


	2014			2013			2012
			Grant Date			Grant Date			Grant Date
	Shares		Fair Value (1)	Shares		Fair Value (1)	Shares		Fair Value (1)

Awards outstanding at beginning of year	771,942	$	13.62	1,191,402	$	14.14	1,263,218	$	14.80
Granted	139,455		23.22	168,468		21.63	349,430		16.30
Vested (2) (3)	(356,437)		11.27	(502,022)		17.50	(400,180)		18.07
Forfeited	-		-	(85,906)		13.79	(21,066)		15.00
Awards outstanding at end of year (3)	554,960	$	17.54	771,942	$	13.62	1,191,402	$	14.14

(1) Represents the weighted average grant date fair value, which is based on the quoted market price of our common stock on the business day prior to the date of grant.

(2) Total fair value of restricted stock and RSUs that vested during the years ended December 31, 2014, 2013 and 2012 was $8.2 million, $11.0 million and $6.7 million, respectively.

Shareholders' Equity (Tables)

12 Months Ended

Dec. 31, 2014

Shareholders' Equity [Abstract]

Components Of Accumulated Other Comprehensive Income (Loss)


		2014		2013

Cumulative foreign currency translation adjustment	$	(30,161)	$	(10,697)
Unrealized loss on hedges, net (1)		(32,091)		(9,991)
Accumulated other comprehensive loss	$	(62,252)	$	(20,688)

(1)

Commitments And Contingencies And Other Matters (Tables)

12 Months Ended

Dec. 31, 2014

Commitments And Contingencies And Other Matters [Abstract]

Schedule of Future Minimum Rental Payments for Operating Leases


				Facilities
		Vessels		and Other		Total

2015	$	134,964	$	5,019	$	139,983
2016		159,334		4,570		163,904
2017		160,433		4,391		164,824
2018		126,890		4,418		131,308
2019		122,004		4,478		126,482
Thereafter		282,879		20,714		303,593
Total lease commitments	$	986,504	$	43,590	$	1,030,094

Business Segment Information (Tables)

12 Months Ended

Dec. 31, 2014

Business Segment Information [Abstract]

Schedule Of Segment Reporting Information By Segment


		Year Ended December 31,
		2014		2013		2012
Net revenues —
Well Intervention	$	667,849	$	452,452	$	378,546
Robotics		420,224		333,246		328,726
Production Facilities		93,175		88,149		80,091
Subsea Construction		358		71,321		192,521
Intercompany elimination		(74,450)		(68,607)		(133,775)
Total	$	1,107,156	$	876,561	$	846,109

Income (loss) from operations —
Well Intervention	$	204,810	$	131,840	$	85,482
Robotics		68,329		44,132		55,678
Production Facilities		41,138		49,778		40,082
Subsea Construction (1)		10,923		33,685		(148,862)
Corporate and other		(62,523)		(77,041)		(92,985)
Intercompany elimination		(921)		(3,360)		(7,878)
Total	$	261,756	$	179,034	$	(68,483)

Net interest expense and other —
Well Intervention	$	(6,915)	$	(217)	$	2,152
Robotics		7,304		(210)		(1,203)
Production Facilities		384		380		365
Subsea Construction		(278)		480		(247)
Corporate and eliminations (2)		(381)		37,978		64,882
Total	$	114	$	38,411	$	65,949

Equity in earnings of equity investments	$	879	$	2,965	$	8,434


Income (loss) before income taxes —
Well Intervention	$	211,725	$	132,057	$	83,205
Robotics		61,025		44,342		56,881
Production Facilities		41,633		52,363		48,276
Subsea Construction		11,201		33,205		(148,615)
Corporate and eliminations		(63,063)		(118,379)		(165,745)
Total	$	262,521	$	143,588	$	(125,998)

Income tax provision (benefit) —
Well Intervention	$	50,102	$	26,718	$	15,400
Robotics		21,612		15,530		20,222
Production Facilities		14,395		17,233		15,784
Subsea Construction		3,881		11,655		(51,329)
Corporate and eliminations		(23,019)		(39,524)		(59,235)
Total	$	66,971	$	31,612	$	(59,158)


Identifiable assets —
Well Intervention	$	1,470,349	$	1,245,229	$	936,926
Robotics		299,701		282,373		258,117
Production Facilities		459,427		495,829		504,828
Subsea Construction		27,547		38,054		303,479
Corporate and other		443,674		482,795		483,003
Discontinued operations		-		-		900,227
Total	$	2,700,698	$	2,544,280	$	3,386,580

Capital expenditures —
Well Intervention	$	283,635	$	283,132	$	274,451
Robotics		51,348		39,655		44,500
Production Facilities		869		1,252		823
Corporate and other		1,060		387		3,265
Total	$	336,912	$	324,426	$	323,039


Depreciation and amortization —
Well Intervention	$	57,570	$	44,619	$	37,736
Robotics		24,478		22,263		19,933
Production Facilities		21,278		17,193		16,828
Subsea Construction		-		8,651		19,773
Corporate and eliminations		6,019		5,809		2,931
Total	$	109,345	$	98,535	$	97,201

Summary Of Intercompany Segment Revenues


		Year Ended December 31,
		2014		2013		2012

Well Intervention	$	29,875	$	22,448	$	36,781
Robotics		44,575		41,169		46,465
Production Facilities		-		4,673		46,057
Subsea Construction		-		317		4,472
Total	$	74,450	$	68,607	$	133,775

Intercompany Segment Gross Profit (Losses)


		Year Ended December 31,
		2014		2013		2012

Well Intervention	$	(323)	$	(141)	$	6,203
Robotics		1,419		3,518		180
Production Facilities		(175)		(175)		(175)
Subsea Construction		-		158		1,670
Total	$	921	$	3,360	$	7,878

Schedule of Revenue from External Customers by Geographic Area


		Year Ended December 31,
		2014		2013		2012

United States	$	403,994	$	345,525	$	281,308
North Sea (1)		504,016		403,816		345,074
Other		199,146		127,220		219,727
Total	$	1,107,156	$	876,561	$	846,109

(1) Includes revenues of $362.7 million, $327.1 million and $283.1 million, respectively, which were from the United Kingdom during years ended December 31, 2014, 2013 and 2012.

Schedule of Long-Lived Assets by Geographic Area


		Year Ended December 31,
		2014		2013		2012

United States	$	913,422	$	1,119,075	$	1,180,586
United Kingdom		355,996		336,317		304,062
Luxembourg		465,875		76,749		-
Other		91		76		1,227
Total	$	1,735,384	$	1,532,217	$	1,485,875

- Definition

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

+ References+ Details

Oil And Gas Properties (Tables)

12 Months Ended

Dec. 31, 2014

Oil And Gas Properties [Abstract]

Results of Operations for Oil and Gas Producing Activities Disclosure


		Year Ended December 31,
		2013 (1)		2012

Revenues	$	48,847	$	557,231
Costs:
Production (lifting) costs		16,017		164,663
Hurricane repair expense		-		662
Exploration expenses		3,514		3,295
Depreciation, depletion, amortization and accretion		1,226		158,284
Proved property impairment and abandonment (2)		(152)		151,045
Loss on sale of oil and gas properties		-		1,714
Hedge ineffectiveness and non-hedge gain on commodity derivative contracts		-		(5,550)
Selling, general and administrative expenses		1,229		17,823
Net interest expense and other (3)		2,732		28,191
Total costs		24,566		520,127
Pretax income from discontinued operations		24,281		37,104
Income tax provision		8,499		13,420
Income from operations of discontinued operations		15,782		23,684
Loss on sale of business, net of tax		(14,709)		-
Income from discontinued operations, net of tax	$	1,073	$	23,684

(2) Results for 2012 include a charge of $138.6 million to reduce our carrying amount of ERT to its estimated fair value less costs to sell.

- Definition

Tabular disclosure of the results of operations for oil and gas producing activities for the year.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

-SubTopic 235

-Section 55

-Paragraph 5

-URI http://asc.fasb.org/extlink&oid=34713648&loc=d3e63071-109448

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 410

-SubTopic 20

-Section 50

-Paragraph 1

-Subparagraph (c)(3)

-URI http://asc.fasb.org/extlink&oid=6392692&loc=d3e7535-110849

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

-SubTopic 235

-Section 50

-Paragraph 23

-URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62136-109447

Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

-SubTopic 235

-Section 50

-Paragraph 24

-URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62246-109447

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

-SubTopic 235

-Section 50

-Paragraph 27

-URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62352-109447

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

-SubTopic 10

-Section S99

-Paragraph 1

-Subparagraph (SX 210.4-10.(a)(17)(ii),(c)(3)(ii)(A)(1))

-URI http://asc.fasb.org/extlink&oid=27015464&loc=d3e511914-122862

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

-SubTopic 235

-Section 50

-Paragraph 25

-URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62259-109447

Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

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-Section 50

-Paragraph 26

-URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62299-109447

Reference 9: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

-SubTopic 235

-Section 50

-Paragraph 22

-URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62094-109447

Reference 10: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 932

-SubTopic 235

-Section 50

-Paragraph 28

-URI http://asc.fasb.org/extlink&oid=8451039&loc=d3e62395-109447

+ Details

Allowance Accounts (Tables)

12 Months Ended

Dec. 31, 2014

Allowance Accounts [Abstract]

Summary of Valuation Allowance


		Allowance		Deferred
		for		Tax Asset
		Uncollectible		Valuation
		Accounts		Allowance

Balance at December 31, 2011	$	4,000	$	14,310
Additions (1)		1,257		2,081
Deductions		(105)		-
Balance at December 31, 2012		5,152		16,391
Additions (2)		2,236		6,469
Deductions (3)		(5,154)		-
Balance at December 31, 2013	$	2,234	$	22,860
Additions (4)		5,331		216
Deductions (5)		(2,830)		-
Balance at December 31, 2014	$	4,735	$	23,076

(2) The increase in valuation allowance includes $6.5 million related to our net operating losses generated in Australia.

(5) The decrease reflects the write-offs of trade receivables deemed uncollectible.

Derivative Instruments And Hedging Activities (Tables)

12 Months Ended

Dec. 31, 2014

Derivative Instruments And Hedging Activities [Abstract]

Derivatives Designated As Hedging Instruments


	As of December 31, 2014			As of December 31, 2013
	Balance Sheet		Fair	Balance Sheet		Fair
	Location		Value	Location		Value
Asset Derivatives:
Interest rate swaps	Other assets, net	$	369	Other assets, net	$	446
		$	369		$	446

Liability Derivatives:
Foreign exchange contracts	Accrued liabilities	$	12,661	Accrued liabilities	$	1,905
Interest rate swaps	Accrued liabilities		561	Accrued liabilities		746
Foreign exchange contracts	Other non-current liabilities		37,767	Other non-current liabilities		13,166
		$	50,989		$	15,817

Derivatives Not Designated As Hedging Instruments


	As of December 31, 2014			As of December 31, 2013
	Balance Sheet		Fair	Balance Sheet		Fair
	Location		Value	Location		Value
Asset Derivatives:
Foreign exchange contracts	Other current assets	$	-	Other current assets	$	69
		$	-		$	69

Impact Of Derivative Instruments On Accumulated Comprehensive Income (Loss)


		Gain (Loss) Recognized in OCI
		on Derivatives, Net of Tax
		(Effective Portion)
		Year Ended December 31,
		2014		2013		2012

Foreign exchange contracts	$	(22,170)	$	(9,796)	$	-
Oil and gas commodity contracts		-		-		(12,860)
Interest rate swaps		70		(195)		(81)
	$	(22,100)	$	(9,991)	$	(12,941)

Gain (Loss) Reclassified From Accumulated OCI Into Income


			Gain (Loss) Reclassified from
	Location of Gain (Loss)		Accumulated OCI into Earnings
	Reclassified from		(Effective Portion)
	Accumulated OCI into Earnings		Year Ended December 31,
	(Effective Portion)		2014		2013		2012

Oil and gas commodity contracts	Income from discontinued operations, net of tax	$	-	$	-	$	3,184
Interest rate swaps	Net interest expense		(858)		(152)		(523)
Foreign exchange contracts	Cost of sales		(2,507)		(1,324)		-
		$	(3,365)	$	(1,476)	$	2,661

Impact Of Non Designated Derivative Instruments On Income Statement


			Gain (Loss) Recognized
	Location of Gain (Loss)		in Earnings on Derivatives
	Recognized in Earnings		Year Ended December 31,
	on Derivatives		2014		2013		2012

Oil and gas commodity contracts	Income from discontinued operations, net of tax	$	-	$	-	$	5,550
Oil and gas commodity contracts	Loss on commodity derivative contracts		-		(14,113)		(10,507)
Interest rate swaps	Other expense, net		-		(86)		(567)
Foreign exchange contracts	Other expense, net		7		(630)		411
		$	7	$	(14,829)	$	(5,113)

Quarterly Financial Information (Tables)

12 Months Ended

Dec. 31, 2014

Quarterly Financial Information Disclosure [Abstract]

Schedule of Quarterly Financial Information


		Quarter Ended
		March 31,		June 30,		September 30,		December 31,
2014
Net revenues	$	253,572	$	305,587	$	340,837	$	207,160
Gross profit	$	75,846	$	109,138	$	126,247	$	32,805
Net income applicable to Helix	$	53,719	$	57,782	$	75,586	$	7,960
Basic earnings per common share	$	0.51	$	0.55	$	0.72	$	0.08
Diluted earnings per common share	$	0.51	$	0.55	$	0.71	$	0.08


		Quarter Ended
		March 31,		June 30,		September 30,		December 31,
2013
Net revenues (1)	$	197,429	$	232,178	$	220,117	$	226,837
Gross profit (2)		52,567		67,497		69,457		71,164
Net income applicable to Helix:
Income from continuing operations	$	557	$	27,240	$	44,549	$	36,503
Income (loss) from discontinued operations		1,058		(29)		44		-
Net income applicable to Helix	$	1,615	$	27,211	$	44,593	$	36,503
Basic earnings per common share:
Income from continuing operations	$	0.01	$	0.26	$	0.42	$	0.35
Income from discontinued operations		0.01		-		-		-
Basic earnings per common share	$	0.02	$	0.26	$	0.42	$	0.35
Diluted earnings per common share:
Income from continuing operations	$	0.01	$	0.26	$	0.42	$	0.35
Income from discontinued operations		0.01		-		-		-
Diluted earnings per common share	$	0.02	$	0.26	$	0.42	$	0.35

(1) Excludes revenues from discontinued operations of $48.8 million for the quarter ended March 31, 2013.

(2) Excludes gross profit from discontinued operations of $28.2 million for the quarter ended March 31, 2013.

Organization (Details) (USD $) In Millions, unless otherwise specified	1 Months Ended	12 Months Ended
	Feb. 28, 2013	Dec. 31, 2014 segment
Organization [Abstract]
Number of reportable segments		4
Proceeds from divestiture of business	$ 624

Summary Of Significant Accounting Policies (Statement Of Cash Flow Information - Narrative) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Summary Of Significant Accounting Policies [Abstract]
Accruals for capital expenditures	$ 14.1	$ 9.5
Noncash consideration received	$ 27.5

Summary Of Significant Accounting Policies (Supplemental Cash Flow Information) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary Of Significant Accounting Policies [Abstract]
Interest paid, net of interest capitalized	$ 11,628	$ 39,040	$ 68,735
Income taxes paid	$ 70,509	$ 113,331	$ 43,111

Summary Of Significant Accounting Policies (Property And Equipment - Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended		8 Months Ended		10 Months Ended	12 Months Ended			12 Months Ended	15 Months Ended	12 Months Ended		1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014 Spoolbase Facility [Member]	Jan. 31, 2014 Spoolbase Facility [Member]	Jan. 31, 2014 Spoolbase Facility [Member]	Jan. 31, 2015 Spoolbase Facility [Member]	Jul. 31, 2013 Express, Caesar And Other Pipelay Equipment [Member]	Dec. 31, 2012 Express, Caesar And Other Pipelay Equipment [Member]	Dec. 31, 2013 Caesar [Member]	Dec. 31, 2012 Caesar [Member]	Dec. 31, 2013 Express [Member]	Dec. 31, 2013 Express [Member]	Dec. 31, 2012 Equipment In Australia [Member]	Dec. 31, 2012 Intrepid Vessel [Member]	Jan. 31, 2015 Subsequent Event [Member] Spoolbase Facility [Member]
Property, Plant and Equipment [Line Items]
Cost of Property Repairs and Maintenance	$ 44,600,000	$ 31,500,000	$ 39,300,000
Capitalized Computer Software, Gross	17,400,000	17,500,000
Capitalized Computer Software, Net	3,900,000	4,800,000
Capitalized Computer Software, Amortization	1,300,000	1,800,000	2,600,000
Asset impairment									157,800,000					4,600,000	14,600,000
Proceeds from sale of assets	13,574,000	189,054,000	19,530,000	2,500,000		15,000,000		238,300,000					100,000,000		14,500,000	7,500,000
Sales Price Of Property Plant And Equipment					45,000,000
Deposit liability current		5,000,000
Noncash consideration received	27,500,000
Note receivable, interest rate				6.00%
Note receivable					30,000,000	30,000,000										20,000,000
Note receivable, current	17,500,000						10,000,000
Note receivable, noncurrent	10,000,000						10,000,000
Gain (Loss) on sale of assets and asset impairment charges										(1,100,000)		15,600,000			(13,500,000)
Aggregate fair value of properties											138,300,000			5,000,000	28,000,000
Capitalized interest	$ 10,419,000	$ 10,419,000	$ 4,893,000

Summary Of Significant Accounting Policies (Property, Plant And Equipment) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property and equipment	$ 2,241,444	$ 1,963,706
Vessels [Member]
Property, Plant and Equipment [Line Items]
Property and equipment	1,657,448	1,403,573
ROVs Trenchers And ROVDrills [Member]
Property, Plant and Equipment [Line Items]
Property and equipment	310,841	271,801
Property, plant and equipment, useful life	10 years
Machinery, Equipment, Buildings And Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Property and equipment	$ 273,155	$ 288,332
Maximum [Member] \| Vessels [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	30 years
Maximum [Member] \| Machinery, Equipment, Buildings And Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	30 years
Minimum [Member] \| Vessels [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	15 years
Minimum [Member] \| Machinery, Equipment, Buildings And Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	5 years

Summary Of Significant Accounting Policies (Goodwill - Narrative and Schedule Of Goodwill) (Details) (USD $) In Thousands, unless otherwise specified	0 Months Ended	12 Months Ended
	Nov. 01, 2014 segment	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2014 Well Intervention [Member]	Dec. 31, 2013 Well Intervention [Member]	Dec. 31, 2014 Robotics [Member]	Dec. 31, 2013 Robotics [Member]	Dec. 31, 2012 Robotics [Member]
Goodwill [Line Items]
Number of reporting units	2
Goodwill, Beginning Balance		$ 63,230	$ 62,935	$ 18,123	$ 17,828	$ 45,107	$ 45,107	$ 45,107
Goodwill, Other Changes		(1,084)	295	(1,084)	295
Goodwill, Ending Balance		$ 62,146	$ 63,230	$ 17,039	$ 18,123	$ 45,107	$ 45,107	$ 45,107

Summary Of Significant Accounting Policies (Recertification Costs And Deferred Dry Dock Charges - Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Deferred dry dock expenses, net	$ 11,631,000	$ 20,833,000
Accumulated Amortization Deferred Drydock	7,500,000	14,500,000
Drydock amortization expense	$ 14,100,000	$ 14,800,000	$ 8,600,000
Minimum [Member]
Drydock Amortization Period	30 months
Drydock Recertification Process Period	1 month
Maximum [Member]
Drydock Amortization Period	60 months
Drydock Recertification Process Period	2 months

Summary Of Significant Accounting Policies (Foreign Currency - Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary Of Significant Accounting Policies [Abstract]
Foreign currency translation gain (loss)	$ (19,464,000)	$ 4,970,000	$ 7,291,000
Foreign currency transaction gain (loss)	$ 2,500,000	$ 700,000	$ (500,000)

- Definition

Amount after tax, before reclassification adjustments of gain (loss) on foreign currency translation adjustments, foreign currency transactions designated and effective as economic hedges of a net investment in a foreign entity and intra-entity foreign currency transactions that are of a long-term-investment nature.

+ References+ Details

Summary Of Significant Accounting Policies (Earnings Per Share - Narrative) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012 Convertible Senior Notes 2025 [Member]	Dec. 31, 2012 Convertible Senior Notes 2025 [Member]	Dec. 31, 2014 Convertible Senior Notes 2032 [Member]	Dec. 31, 2013 Convertible Senior Notes 2032 [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Anti-dilutive securities		9,300	8,000	8,000
Convertible debt stock price trigger	$ 38.57

- Definition

Securities (including those issuable pursuant to contingent stock agreements) that could potentially dilute basic earnings per share (EPS) or earnings per unit (EPU) in the future that were not included in the computation of diluted EPS or EPU because to do so would increase EPS or EPU amounts or decrease loss per share or unit amounts for the period presented.

+ References+ Details

Summary Of Significant Accounting Policies (Computations Of Basic And Diluted EPS) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary Of Significant Accounting Policies [Abstract]
Net income (loss) applicable to Helix	$ 7,960	$ 75,586	$ 57,782	$ 53,719	$ 36,503	$ 44,593	$ 27,211	$ 1,615	$ 195,047	$ 109,922	$ (46,334)
Income from discontinued operations, net of tax						(44)	29	(1,058)		(1,073)	(23,684)
Net income from continuing operations					36,503	44,549	27,240	557	195,047	108,849	(70,018)
Less: Undistributed net income allocable to participating securities									(1,018)	(801)
Net income applicable to common shareholders - continuing operations									194,029	108,048	(70,018)
Less: Undistributed net income from discontinued operations allocable to participating securities										(8)
Net income applicable to common shareholders - discontinued operations										1,065	23,684
Weighted average number of shares outstanding - basic									105,029	105,032	104,449
Share-based awards other than participating securities, shares									16	152
Undistributed earnings reallocated to participating securities, value										1
Net income applicable to Helix - Diluted									194,029	108,049	(70,018)
Weighted average number of shares outstanding, diluted									105,045	105,184	104,449
Income from discontinued operations, net of tax						$ 44	$ (29)	$ 1,058		$ 1,073	$ 23,684

Summary Of Significant Accounting Policies (Excluded Securities On Diluted Shares Calculation) (Details) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Diluted (in shares)	105,045	105,184	104,449
Total			105,165
Share-based Awards [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Anti-dilutive securities			382
Convertible Preferred Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Anti-dilutive securities			334

- Definition

+ References+ Details

Summary Of Significant Accounting Policies (Major Customers And Concentration Of Credit Risk - Narrative) (Details)	12 Months Ended
	Dec. 31, 2014 Anadarko [Member]	Dec. 31, 2013 Shell [Member]	Dec. 31, 2012 Shell [Member]
Revenue, Major Customer [Line Items]
Concentration Risk, Percentage	13.00%	14.00%	12.00%

Summary Of Significant Accounting Policies (Assets And Liabilities Measured At Fair Value On A Recurring Basis) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total net liability	$ 648,913	$ 660,989
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total net liability	222,900	242,250
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total net liability	426,013	418,739
Foreign Exchange Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		69
Foreign Exchange Contracts [Member] \| Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets		69
Interest Rate Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	369	446
Interest Rate Swaps [Member] \| Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	369	446
Fair Value Of Long Term Debt [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	598,293	645,687
Fair Value Of Long Term Debt [Member] \| Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	222,900	242,250
Fair Value Of Long Term Debt [Member] \| Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	375,393	403,437
Foreign Exchange Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	50,428	15,071
Foreign Exchange Contracts [Member] \| Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	50,428	15,071
Interest Rate Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	561	746
Interest Rate Swaps [Member] \| Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities	$ 561	$ 746

Summary Of Significant Accounting Policies (Value Of Long Term Debt) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Mar. 31, 2012
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt, carrying value	$ 572,292	$ 592,668
Long-term debt, Fair Value	598,293	645,687
Unamortized debt discount	20,920	26,516
Term Loan Maturing June 2018 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt, carrying value	277,500	292,500
Long-term debt, Fair Value	270,563	293,963
Convertible Senior Notes 2032 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt, carrying value	200,000	200,000	200,000
Long-term debt, Fair Value	222,900	242,250
Unamortized debt discount	20,920	26,500	35,400
MARAD Debt [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt, carrying value	94,792	100,168
Long-term debt, Fair Value	$ 104,830	$ 109,474

Summary Of Significant Accounting Policies (Debt Discount - Narrative) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Mar. 31, 2012
Debt Instrument [Line Items]
Unamortized debt discount	$ 20,920	$ 26,516
Convertible Senior Notes 2032 [Member]
Debt Instrument [Line Items]
Unamortized debt discount	$ 20,920	$ 26,500	$ 35,400
Expected life used to estimate fair value	6 years

Summary Of Significant Accounting Policies (Convertible Preferred Stock - Narrative) (Details) (USD $) In Millions, except Share data, unless otherwise specified	1 Months Ended
	Dec. 31, 2012
Summary Of Significant Accounting Policies [Abstract]
Value of convertible preferred stock	$ 1
Stock issued during period, shares, conversion of convertible securities	361,402

- Definition

Number of shares issued during the period as a result of the conversion of convertible securities.

+ References+ Details

Details Of Certain Accounts (Other Current Assets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Details Of Certain Accounts [Abstract]
Note receivable	$ 17,500
Other receivables	423	785
Prepaid insurance	6,582	7,038
Other prepaids	15,541	12,999
Spare parts inventory	1,857	1,038
Value added tax receivable	9,326	7,589
Other	72	260
Total other current assets	$ 51,301	$ 29,709

- Definition

An amount representing an agreement for an unconditional promise by the maker to pay the Entity (holder) a definite sum of money at a future date(s) within one year of the balance sheet date or the normal operating cycle, whichever is longer. Such amount may include accrued interest receivable in accordance with the terms of the debt. The debt also may contain provisions including a discount or premium, payable on demand, secured, or unsecured, interest bearing or noninterest bearing, among a myriad of other features and characteristics. This amount does not include amounts related to receivables held-for-sale.

+ References+ Details

- Definition

Amount of asset related to consideration paid in advance for insurance that provides economic benefits within a future period of one year or the normal operating cycle, if longer.

+ References+ Details

Details Of Certain Accounts (Other Assets, Net) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Details Of Certain Accounts [Abstract]
Note receivable	$ 10,000
Deferred dry dock expenses, net (Note 2)	11,631	20,833
Deferred financing costs, net (Note 6)	23,399	24,297
Intangible assets with finite lives, net	696	622
Charter fee deposit (Note 11)	12,544
Other	1,002	1,515
Total other assets, net	$ 59,272	$ 47,267

Details Of Certain Accounts (Accrued Liabilities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Details Of Certain Accounts [Abstract]
Accrued payroll and related benefits	$ 61,246	$ 50,527
Current asset retirement obligations	575	2,024
Unearned revenue	11,461	19,608
Billing in excess of cost		1,677
Accrued interest	4,221	4,187
Derivative liability (Note 15)	13,222	2,651
Taxes payable excluding income tax payable	6,236	4,811
Pipelay assets sale deposit		5,000
Other	7,962	5,997
Total accrued liabilities	$ 104,923	$ 96,482

Equity Investments (Details) (USD $)	12 Months Ended
Equity Investments (Details) (USD $)	Dec. 31, 2014 ft item	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Number of equity investments	2
Equity investments in unconsolidated affiliates	$ 149,623,000	$ 157,919,000
Water depth	8,000
Deepwater Gateway, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	50.00%
Equity investments in unconsolidated affiliates	80,900,000	85,800,000
Capitalized interest	1,200,000	1,300,000
Independence Hub, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	20.00%
Equity investments in unconsolidated affiliates	68,800,000	72,100,000
Capitalized interest	$ 3,900,000	$ 4,300,000

Kommandor LLC (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Feb. 28, 2014	Dec. 31, 2013
Kommandor LLC [Abstract]
Oil and gas processing equipment, percentage of cost	100.00%
Ownership percentage			81.00%
Acquisition of noncontrolling interests	$ 20,085
Noncontrolling interest, ownership percentage of noncontrolling owners		19.00%

Long-Term Debt (Credit Agreement) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended		1 Months Ended				12 Months Ended			1 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2014	Sep. 30, 2013 Interest Rate Swaps [Member]	Jul. 31, 2013 Term Loan Maturing June 2018 [Member]	Dec. 31, 2014 Term Loan Maturing June 2018 [Member]	Jun. 30, 2013 Term Loan Maturing June 2018 [Member]	Sep. 30, 2013 Term Loan Maturing June 2018 [Member] Interest Rate Swaps [Member]	Dec. 31, 2014 Term Loan Maturing June 2018 [Member] London Interbank Offered Rate (LIBOR) [Member]	Dec. 31, 2014 Revolving Credit Facility Maturing June 2018 [Member]	Jun. 30, 2013 Revolving Credit Facility Maturing June 2018 [Member]	Jul. 31, 2013 Senior Unsecured Notes [Member]	Mar. 31, 2012 Senior Unsecured Notes [Member]	Dec. 31, 2014 Minimum [Member] Term Loan Maturing June 2018 [Member]	Dec. 31, 2014 Minimum [Member] Loans [Member] London Interbank Offered Rate (LIBOR) [Member]	Dec. 31, 2014 Maximum [Member] Term Loan Maturing June 2018 [Member]	Dec. 31, 2014 Maximum [Member] Loans [Member] London Interbank Offered Rate (LIBOR) [Member]	Dec. 31, 2014 Years One And Two [Member] Term Loan Maturing June 2018 [Member]	Dec. 31, 2014 Years Three Through Five [Member] Term Loan Maturing June 2018 [Member]
Debt Instrument [Line Items]
Original borrowing capacity					$ 300				$ 600
Line of credit facility, maximum additional commitments								200
Proceeds from unsecured lines of credit			300
Repayments of debt										275.0	200.0
Revolving credit facility available								583.6
Unsecured letters of credit								16.4
Basis point spread							2.25%					1.00%	2.00%	2.00%	3.00%
Commitment fee percentage								0.375%
Notional amount of derivative		148.1
Derivative, lower range of basis spread on variable rate						0.74%
Derivative, higher range of basis spread on variable rate						0.75%
Debt instrument, periodic payment, principal, percentage																5.00%	10.00%
Debt instrument, periodic payment, principal																15.0	30.0
Debt instrument, periodic payment terms, balloon payment to be paid				$ 180.0
Debt intstrument, maturity date	Jun. 19, 2018

Long-Term Debt (Convertible Senior Notes Dues 2032) (Details) (USD $)	12 Months Ended		1 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Mar. 31, 2012 Convertible Senior Notes 2032 [Member]	Dec. 31, 2014 Convertible Senior Notes 2032 [Member]	Dec. 31, 2013 Convertible Senior Notes 2032 [Member]	Mar. 31, 2012 Convertible Senior Notes 2025 [Member]	Mar. 31, 2005 Convertible Senior Notes 2025 [Member]
Debt Instrument [Line Items]
Long-term debt, carrying value	$ 572,292,000	$ 592,668,000	$ 200,000,000	$ 200,000,000	$ 200,000,000		$ 300,000,000
Debt instrument interest rate			3.25%				3.25%
Proceeds from issuance of debt			195,000,000
Debt instrument, repurchase amount						142,200,000
Debt instrument, frequency of periodic payment				semi-annually
Debt intstrument, maturity date	Jun. 19, 2018			Mar. 15, 2032
Convertible Senior Notes, shares of common stock				39.9752
Base principal amount				1,000
Per share conversion price				$ 25.02
Issuance of notes, percentage				100.00%
Unamortized debt discount	20,920,000	26,516,000	35,400,000	20,920,000	26,500,000
Expected life used to estimate fair value				6 years
Effective interest rate				6.90%			6.60%
Carrying amount of equity component	$ 22,500,000

Long-Term Debt (MARAD Debt) (Details) (MARAD Debt [Member])	12 Months Ended
	Dec. 31, 2014	Sep. 30, 2005
MARAD Debt [Member]
Debt Instrument [Line Items]
Debt instrument, frequency of periodic payment	semi-annual
Debt instrument, maturity date	February 2027
Guarantor obligations, liquidation proceeds, percentage	50.00%
Basis point spread	0.20%
Debt instrument interest rate		4.93%

Long-Term Debt (Nordea Credit Agreement) (Details) (Nordea Term Loan [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014
Debt Instrument [Line Items]
Original borrowing capacity		$ 250
Commitment fee percentage	0.875%
Debt instrument, term	5 years
Debt instrument, frequency of periodic payment	quarterly
Debt instrument, periodic payment, principal	8.9
Debt instrument, periodic payment terms, balloon payment to be paid	$ 80.4
London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Basis point spread	2.50%

Long-Term Debt (Former Credit Facility) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended			1 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 28, 2013 Former Credit Facility [Member]	Dec. 31, 2013 Former Term Loan [Member]
Debt Instrument [Line Items]
Repayment of Helix Term Notes	$ 15,000	$ 374,681	$ 12,569	$ 318,400
Amortization of deferred financing costs	$ 4,870	$ 5,187	$ 9,086		$ 3,500

Long-Term Debt (Senior Unsecured Debt) (Details) (USD $)	12 Months Ended			1 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jul. 31, 2013 Senior Unsecured Notes [Member]	Mar. 31, 2012 Senior Unsecured Notes [Member]	Dec. 31, 2013 Senior Unsecured Notes [Member]	Dec. 31, 2012 Senior Unsecured Notes [Member]	Dec. 31, 2007 Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Senior Unsecured Notes amount issued								$ 550,000,000
Debt instrument interest rate								9.50%
Repayments of debt				275,000,000	200,000,000
Payment On Senior Unsecured Notes		281,490,000	209,500,000	282,000,000	213,500,000
Payment of debt extinguishment costs				6,500,000	9,500,000
Interest paid				500,000	4,000,000
Loss on early extinguishment of debt		12,100,000	17,127,000		11,500,000	8,600,000
Amortization of deferred financing costs	4,870,000	5,187,000	9,086,000		2,000,000	2,100,000
Long-term debt	$ 523,228,000	$ 545,776,000					$ 275,000,000

Long-Term Debt (Convertible Senior Notes Due 2025 and Other) (Details) (USD $)	12 Months Ended			1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 28, 2013 Convertible Senior Notes 2025 [Member]	Dec. 31, 2012 Convertible Senior Notes 2025 [Member]	Mar. 31, 2012 Convertible Senior Notes 2025 [Member]	Mar. 31, 2005 Convertible Senior Notes 2025 [Member]
Debt Instrument [Line Items]
Long-term debt, carrying value	$ 572,292,000	$ 592,668,000					$ 300,000,000
Debt instrument interest rate							3.25%
Debt instrument issued percentage							100.00%
Effective interest rate							6.60%
Debt instrument, repurchase amount						142,200,000
Repayments of debt						145,100,000
Interest paid						1,100,000
Payment of debt extinguishment costs						1,800,000
Amortization of deferred financing costs	4,870,000	5,187,000	9,086,000			300,000
Loss on early extinguishment of debt		12,100,000	17,127,000			5,600,000
Repayment of Helix Term Notes	15,000,000	374,681,000	12,569,000	3,500,000	154,300,000
Amortization of debt discount	5,596,000	5,172,000	9,729,000			3,500,000
Deferred financing costs	$ 3,586,000	$ 10,954,000	$ 7,580,000

Long-Term Debt (Schedule of Long-Term Debt) (Details) (USD $) In Thousands, unless otherwise specified			12 Months Ended		12 Months Ended				12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2014 Term Loan Maturing June 2018 [Member]	Dec. 31, 2013 Term Loan Maturing June 2018 [Member]	Dec. 31, 2014 Convertible Senior Notes 2032 [Member]	Dec. 31, 2013 Convertible Senior Notes 2032 [Member]	Mar. 31, 2012 Convertible Senior Notes 2032 [Member]	Dec. 31, 2012 Senior Unsecured Notes [Member]	Dec. 31, 2014 MARAD Debt [Member]	Dec. 31, 2013 MARAD Debt [Member]
Debt Instrument [Line Items]
Total debt	$ 551,372	$ 566,152	$ 277,500	$ 292,500	$ 200,000	$ 200,000			$ 94,792	$ 100,168
Current maturities	(28,144)	(20,376)	(22,500)						(5,644)
Long-term debt, less current maturities	523,228	545,776	255,000		179,080			275,000	89,148
Unamortized debt discount	$ (20,920)	$ (26,516)			$ (20,920)	$ (26,500)	$ (35,400)
Maturity date			June 2018		March 2032				February 2027

- Definition

Carrying amount of long-term debt, net of unamortized discount or premium, including current and noncurrent amounts. Includes, but not limited to, notes payable, bonds payable, debentures, mortgage loans and commercial paper. Excludes capital lease obligations.

+ References+ Details

Long-Term Debt (Schedule of Deferred Financing Costs) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Gross Carrying Amount	$ 36,458	$ 32,872
Accumulated Amortization	(13,059)	(8,575)
Net	23,399	24,297
Term Loan Maturing June 2018 [Member]
Debt Instrument [Line Items]
Gross Carrying Amount	3,638	3,638
Accumulated Amortization	(1,091)	(364)
Net	2,547	3,274
Revolving Credit Facility Maturing June 2018 [Member]
Debt Instrument [Line Items]
Gross Carrying Amount	13,275	13,275
Accumulated Amortization	(3,982)	(1,327)
Net	9,293	11,948
Convertible Senior Notes 2032 [Member]
Debt Instrument [Line Items]
Gross Carrying Amount	3,759	3,759
Accumulated Amortization	(1,763)	(1,148)
Net	1,996	2,611
MARAD Debt [Member]
Debt Instrument [Line Items]
Gross Carrying Amount	12,200	12,200
Accumulated Amortization	(6,223)	(5,736)
Net	5,977	6,464
Nordea Term Loan [Member]
Debt Instrument [Line Items]
Gross Carrying Amount	3,586
Net	$ 3,586

Long-Term Debt (Maturities Of Long-Term Debt) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Mar. 31, 2012
Debt Instrument [Line Items]
Less than one year	$ 28,144
One to two years	35,926
Two to three years	36,222
Three to four years	201,532
Four to five years	6,858
Over five years	263,610
Total debt	572,292	592,668
Current maturities	(28,144)	(20,376)
Long-term debt, less current maturities	544,148
Unamortized debt discount	(20,920)	(26,516)
Long-term debt	523,228	545,776
Term Loan Maturing June 2018 [Member]
Debt Instrument [Line Items]
Less than one year	22,500
One to two years	30,000
Two to three years	30,000
Three to four years	195,000
Total debt	277,500	292,500
Current maturities	(22,500)
Long-term debt, less current maturities	255,000
Long-term debt	255,000
Debt instrument, maturity date	June 2018
MARAD Debt [Member]
Debt Instrument [Line Items]
Less than one year	5,644
One to two years	5,926
Two to three years	6,222
Three to four years	6,532
Four to five years	6,858
Over five years	63,610
Total debt	94,792	100,168
Current maturities	(5,644)
Long-term debt, less current maturities	89,148
Long-term debt	89,148
Debt instrument, maturity date	February 2027
Convertible Senior Notes 2032 [Member]
Debt Instrument [Line Items]
Over five years	200,000
Total debt	200,000	200,000	200,000
Long-term debt, less current maturities	200,000
Unamortized debt discount	(20,920)	(26,500)	(35,400)
Long-term debt	$ 179,080
Debt instrument, maturity date	March 2032

Long-Term Debt (Interest Expense And Capitalized Interest) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
Interest expense	$ 33,064	$ 44,484	$ 53,601
Interest income	(4,786)	(1,167)	(548)
Capitalized interest	(10,419)	(10,419)	(4,893)
Net interest expense	17,859	32,898	48,160
Energy Resource Technology GOM, Inc [Member]
Debt Instrument [Line Items]
Interest expense		$ 2,800	$ 28,600

Income Taxes (Narrative) (Details) (USD $)	12 Months Ended
Income Taxes (Narrative) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Line Items]
Statutory rate	35.00%	35.00%	35.00%
Valuation allowance	$ 23,076,000	$ 22,860,000
Undistributed earnings of foreign subsidiaries	338,000,000	202,600,000
Unrecognized tax benefits that would impact effective tax rate		3,400,000	3,400,000
Income tax examination, penalties and interest expense	(1,300,000)	200,000	200,000
Income tax examination, penalties and interest accrued		1,300,000
Unrecognized tax benefit, decrease resulting from settlements with taxing authorities	3,400,000
Income tax refund	35,200,000
Helix [Member]
Income Taxes [Line Items]
Reductions for tax positions of prior years	$ 4,723,000		$ 2,785,000

Income Taxes (Schedule Of Components Of Income Tax Expense (Benefit)) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Current	$ 43,817	$ 57,128	$ 6,572
Deferred	23,154	(25,516)	(65,730)
Income Tax Expense (Benefit), Total	66,971	31,612	(59,158)
Domestic	29,613	11,615	(78,211)
Foreign	$ 37,358	$ 19,997	$ 19,053

- Definition

Amount of current income tax expense (benefit) pertaining to taxable income (loss) from continuing operations.

+ References+ Details

- Definition

Amount of other deferred income tax expense (benefit) pertaining to income (loss) from continuing operations. For example, but not limited to, acquisition-date income tax benefits or expenses recognized from changes in the acquirer's valuation allowance for its previously existing deferred tax assets resulting from a business combination and adjustments to beginning-of-year balance of a valuation allowance because of a change in circumstance causing a change in judgment about the realizability of the related deferred tax asset in future periods.

+ References+ Details

Income Taxes (Schedule of Components of Income (Loss) Before Income Taxes) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Domestic	$ 73,700	$ 36,176	$ (256,859)
Foreign	188,821	107,412	130,861
Income (loss) before income taxes	$ 262,521	$ 143,588	$ (125,998)

Income Taxes (Schedule of Income Tax Rate Reconciliation) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Abstract]
Statutory rate	35.00%	35.00%	35.00%
Foreign provision	(9.10%)	(11.60%)	11.20%
Other	(0.40%)	(1.40%)	0.80%
Effective rate	25.50%	22.00%	47.00%

Income Taxes (Schedule Of Deferred Tax Assets And Liabilities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Deferred tax liabilities:
Depreciation	$ 211,903	$ 169,404
Original Issue Discount on 2032 Notes	16,269	14,720
Equity investments in production facilities	50,685	84,870
Prepaid and other	4,211	7,556
Total deferred tax liabilities	283,068	276,550
Deferred tax assets:
Net operating loss	(23,076)	(40,105)
Reserves, accrued liabilities and other	(53,973)	(44,999)
Total deferred tax assets	(77,049)	(85,104)
Valuation allowance	23,076	22,860
Current deferred tax assets	(31,180)	(51,573)
Noncurrent deferred tax liabilities	260,275	265,879
Net deferred tax liabilities	$ 229,095	$ 214,306

Income Taxes (Reconciliation Of Beginning And Ending Amount Of Unrecognized Tax Benefits) (Details) (Helix [Member], USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Helix [Member]
Balance at January 1,	$ 4,723	$ 4,506	$ 7,085
Additions for tax positions of prior years		217	206
Reductions for tax positions of prior years	(4,723)		(2,785)
Balance at December 31,		$ 4,723	$ 4,506

Employee Benefit Plans (Narrative) (Details) (USD $)	12 Months Ended			120 Months Ended			12 Months Ended					1 Months Ended	12 Months Ended				36 Months Ended	1 Months Ended	12 Months Ended			12 Months Ended		12 Months Ended					12 Months Ended
Employee Benefit Plans (Narrative) (Details) (USD $)	Dec. 31, 2014 ShareBasedCompensationPlan	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014	Dec. 31, 2011	Jan. 31, 2015 Subsequent Event [Member]	Dec. 31, 2014 401K Plan [Member]	Dec. 31, 2013 401K Plan [Member]	Dec. 31, 2012 401K Plan [Member]	Dec. 31, 2014 E S P P [Member]	Dec. 31, 2013 E S P P [Member]	Jan. 31, 2014 2005 Incentive Plan [Member]	Dec. 31, 2014 2005 Incentive Plan [Member]	Dec. 31, 2013 2005 Incentive Plan [Member]	Dec. 31, 2012 2005 Incentive Plan [Member]	Dec. 31, 2011 2005 Incentive Plan [Member]	Dec. 31, 2014 2005 Incentive Plan [Member]	Jan. 31, 2015 2005 Incentive Plan [Member] Subsequent Event [Member]	Dec. 31, 2014 Restricted Stock Units RSU And Restricted Stock Shares [Member]	Dec. 31, 2013 Restricted Stock Units RSU And Restricted Stock Shares [Member]	Dec. 31, 2012 Restricted Stock Units RSU And Restricted Stock Shares [Member]	Dec. 31, 2014 Performance Shares [Member]	Jan. 31, 2015 Performance Shares [Member] Subsequent Event [Member]	Dec. 31, 2013 Long-Term Incentive Cash Plan 2009 Grants [Member]	Dec. 31, 2014 Executive Officer [Member]	Dec. 31, 2013 Executive Officer [Member]	Dec. 31, 2012 Executive Officer [Member]	Dec. 31, 2014 Maximum Shares As Incentive Options Member	Dec. 31, 2014 Maximum [Member] Performance Shares [Member]	Dec. 31, 2014 Minimum [Member] Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum employer subscription rate							75.00%	50.00%
Maximum employee subscription rate							5.00%
401k plan cost							$ 2,200,000	$ 1,700,000	$ 1,600,000
Stock authorized shares employee stock purchase plan										1,500,000
Available shares employee stock purchase plan										1,200,000
Percentage of share of non vested stock considered as call option										85.00%
Percentage of share of non-vested stock considered as put-option										15.00%
Allocated share-based compensation expense										1,000,000	800,000
Number of stock plans	1
Additional shares authorized	4,300,000
Shares available for grant	6,200,000			6,200,000																								2,000,000
Share-based payment award, vesting percentage																20.00%	33.00%	33.00%				100.00%
Share-based payment award other than options, grants in period	139,455	168,468	349,430															293,029
Share-based payment award, market value per share																		$ 21.67
Forfeiture on restricted stock percentage	8.00%
Forfeiture on restricted stock period		5 years
Compensation cost related to restricted stock, PSUs and RSUs	10,400,000	8,800,000	7,700,000
Share-based compensation, nonvested awards, total compensation cost not yet recognized																		6,300,000	5,700,000	7,500,000	11,200,000
Share-based payment award, outstanding, weighted average remaining contractual terms																			1 year 2 months 12 days
Performance share units granted	73,609	89,329	132,910															293,029
Performance share unit market value	$ 26.79	$ 27.50	$ 23.68	$ 26.79
Deferred compensation liability																						7,900,000
Share-based payment award, plan modification, incremental compensation cost																						3,300,000
Stock option grants	0			0
Options, outstanding, number		0			192,800
Options, outstanding, weighted average exercise price					$ 10.52
Options, exercises in period		52,800	140,000
Options, exercisable, weighted average exercise price		$ 13.91	$ 9.24
Options, exercises in period, total intrinsic value		500,000	1,300,000
Options, exercisable, intrinsic value			400,000
Minimum percentage of average price during measurement period																								75.00%
Deferred compensation arrangement, cash awards granted, amount	8,900,000	8,400,000	4,200,000	8,900,000		0
Deferred compensation arrangement, compensation expense	7,200,000	9,100,000	8,700,000																						3,600,000	5,300,000	7,300,000
Deferred compensation cash-based arrangement, liability	12,800,000	14,800,000		12,800,000																					7,900,000	11,100,000
Deferred compensation arrangement with individual, distributions paid	$ 9,200,000	$ 7,100,000	$ 5,500,000	$ 9,200,000		$ 8,900,000																	$ 4,500,000
Share-based payment award, vesting period, in years												3 years	3 years	3 years	3 years	5 years		3 years				3 years
Award percentage																													200.00%	0.00%

Employee Benefit Plans (Restricted Shares Granted) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based payment award, shares	139,455	168,468	349,430
Grant Share Amount A [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based payment award, date of grant	Jan. 02, 2014
Share-based payment award, shares	73,609
Share-based payment award, market value per share	$ 23.18
Share-based payment award, vesting percentage	33.00%
Share-based payment award, vesting period, in years	3 years
Grant Share Amount B [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based payment award, date of grant	Jan. 02, 2014
Share-based payment award, shares	73,609
Share-based payment award, market value per share	$ 26.79
Share-based payment award, vesting percentage	100.00%
Share-based payment award, vesting date	Jan. 01, 2017
Grant Share Amount C [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based payment award, date of grant	Jan. 02, 2014
Share-based payment award, shares	2,724
Share-based payment award, market value per share	$ 23.18
Share-based payment award, vesting percentage	100.00%
Share-based payment award, vesting date	Jan. 01, 2016
Grant Share Amount D [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based payment award, date of grant	Apr. 01, 2014
Share-based payment award, shares	4,051
Share-based payment award, market value per share	$ 22.98
Share-based payment award, vesting percentage	100.00%
Share-based payment award, vesting date	Jan. 01, 2016
Grant Share Amount E [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based payment award, date of grant	Jul. 01, 2014
Share-based payment award, shares	3,397
Share-based payment award, market value per share	$ 26.31
Share-based payment award, vesting percentage	100.00%
Share-based payment award, vesting date	Jan. 01, 2016
Grant Share Amount F [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based payment award, date of grant	Oct. 01, 2014
Share-based payment award, shares	3,882
Share-based payment award, market value per share	$ 22.06
Share-based payment award, vesting percentage	100.00%
Share-based payment award, vesting date	Jan. 01, 2016
Grant Share Amount G [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Share-based payment award, date of grant	Dec. 04, 2014
Share-based payment award, shares	51,792
Share-based payment award, market value per share	$ 23.17
Share-based payment award, vesting percentage	33.00%
Share-based payment award, vesting period, in years	3 years

Employee Benefit Plans (Schedule Of Restricted Stock And Restricted Stock Units Activity) (Details) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014 Restricted Stock Units (RSUs) [Member]	Jan. 31, 2014 Restricted Stock Units (RSUs) [Member]	Dec. 31, 2013 Restricted Stock Units (RSUs) [Member]	Jan. 31, 2015 Subsequent Event [Member]	Jan. 31, 2015 Subsequent Event [Member] Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based payment award, nonvested, number, beginning balance	771,942	1,191,402	1,263,218	33,760
Share-based payment award other than options, grants in period	139,455	168,468	349,430
Share-based payment award, vested in period	(356,437)	(502,022)	(400,180)	(33,760)
Share-based payment award, forfeited in period		(85,906)	(21,066)
Share-based payment award, nonvested, number, ending balance	554,960	771,942	1,191,402
Share-based payment award, nonvested, weighted average grant date fair value, beginning balance	$ 13.62	$ 14.14	$ 14.80	$ 15.80
Share-based payment award, grants in period, weighted average grant date fair value	$ 23.22	$ 21.63	$ 16.30
Share-based payment award, vested in period, weighted average grant date fair value	$ 11.27	$ 17.50	$ 18.07
Share-based payment award, forfeitures, weighted average grant date fair value		$ 13.79	$ 15.00
Share-based payment award, nonvested, weighted average grant date fair value, ending balance	$ 17.54	$ 13.62	$ 14.14
Share-based payment award, vested in period, total fair value	$ 8.2	$ 11.0	$ 6.7
Deferred compensation arrangement with individual, distributions paid	9.2	7.1	5.5		0.8		8.9	0.7
Deferred compensation liability				$ 0.2		$ 1.3

Shareholders' Equity (Narrative) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Shareholders' Equity [Abstract]
Common stock, authorized (in shares)	240,000,000	240,000,000
Common stock, par (in dollars per share)
Preferred Stock, Shares Authorized	5,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01

Shareholders' Equity (Components Of Accumulated Other Comprehensive Loss) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Shareholders' Equity [Abstract]
Cumulative foreign currency translation adjustment	$ (30,161,000)	$ (10,697,000)
Unrealized loss on hedges, net	(32,091,000)	(9,991,000)
Accumulated other comprehensive loss	(62,252,000)	(20,688,000)
Deferred tax asset, other comprehensive loss	$ 17,300,000	$ 5,400,000

- Definition

Accumulated change, net of tax, in accumulated gains and losses from derivative instruments designated and qualifying as the effective portion of cash flow hedges. Includes an entity's share of an equity investee's Increase or Decrease in deferred hedging gains or losses.

+ References+ Details

- Definition

Accumulated adjustment, net of tax, that results from the process of translating subsidiary financial statements and foreign equity investments into the reporting currency from the functional currency of the reporting entity, net of reclassification of realized foreign currency translation gains or losses.

+ References+ Details

- Definition

Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge.

+ References+ Details

Stock Buyback Program (Details) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Jun. 30, 2009
Stock Buyback Program [Abstract]
Stock repurchase program, number of shares authorized to be repurchased		1,500,000
Stock repurchased and retired during period, shares	320,911
Stock repurchased and retired during period, value	$ 7.7
Weighted average price of shares repurchased and retired	$ 23.99
Total stock repurchase, shares	3,589,425
Total stock repurchase, value	$ 53.5
Repurchase of common stock, value per share	$ 14.90
Stock repurchase program, remaining number of shares authorized to be repurchased	55,674

Commitments And Contingencies And Other Matters (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended	12 Months Ended		1 Months Ended	12 Months Ended				12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2012 Q5000 [Member]	Dec. 31, 2014 Q5000 [Member]	Dec. 31, 2014 Robotics [Member]	Sep. 30, 2013 Q7000 [Member]	Dec. 31, 2014 Q7000 [Member]	Dec. 31, 2014 Q7000 [Member] Contract Signing [Member]	Dec. 31, 2014 Q7000 [Member] Vessel Delivery [Member]	Dec. 31, 2014 Topside Equipment [Member]	Dec. 31, 2014 Monohull Vessels [Member] property
Commitments And Contingencies [Line Items]
Term Of Charter Agreement						5 years
Long-term purchase commitment				$ 386,500,000			$ 346,000,000
Long-term purchase commitment percentage									20.00%	80.00%
Payments to acquire property, plant, and equipment					289,400,000			69,200,000
Property and equipment	2,241,444,000	1,963,706,000			342,400,000			91,800,000			52,000,000
Number of vessels under construction												2
Charter fee deposit	12,544,000
Operating leases, rent expense, net	147,200,000	102,100,000	85,000,000
Operating leases, rent expense, sublease rentals	800,000	400,000
Operating leases, future minimum payments due, future minimum sublease rentals	$ 2,000,000

Commitments And Contingencies And Other Matters (Lease Commitments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014
Operating Leased Assets [Line Items]
2015	$ 139,983
2016	163,904
2017	164,824
2018	131,308
2019	126,482
Thereafter	303,593
Total lease commitments	1,030,094
Vessels [Member]
Operating Leased Assets [Line Items]
2015	134,964
2016	159,334
2017	160,433
2018	126,890
2019	122,004
Thereafter	282,879
Total lease commitments	986,504
Facilities And Other [Member]
Operating Leased Assets [Line Items]
2015	5,019
2016	4,570
2017	4,391
2018	4,418
2019	4,478
Thereafter	20,714
Total lease commitments	$ 43,590

Business Segment Information (Narrative) (Details)	12 Months Ended
Business Segment Information (Narrative) (Details)	Dec. 31, 2014 segment
Segment Reporting Information [Line Items]
Number of reportable segments	4
Well Intervention [Member]
Segment Reporting Information [Line Items]
Number of vessels under construction	2
Monohull Vessels [Member]
Segment Reporting Information [Line Items]
Number of vessels under construction	2
Number of chartered vessels	2
Robotics [Member]
Segment Reporting Information [Line Items]
Number of chartered vessels	4

Business Segment Information (Summary Of Financial Data By Segment) (Details) (USD $)	3 Months Ended								12 Months Ended																													1 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014 Intercompany Elimination [Member]	Dec. 31, 2013 Intercompany Elimination [Member]	Dec. 31, 2012 Intercompany Elimination [Member]	Dec. 31, 2014 Well Intervention [Member]	Dec. 31, 2013 Well Intervention [Member]	Dec. 31, 2012 Well Intervention [Member]	Dec. 31, 2014 Well Intervention [Member] Intercompany Elimination [Member]	Dec. 31, 2013 Well Intervention [Member] Intercompany Elimination [Member]	Dec. 31, 2012 Well Intervention [Member] Intercompany Elimination [Member]	Dec. 31, 2014 Robotics [Member]	Dec. 31, 2013 Robotics [Member]	Dec. 31, 2012 Robotics [Member]	Dec. 31, 2014 Robotics [Member] Intercompany Elimination [Member]	Dec. 31, 2013 Robotics [Member] Intercompany Elimination [Member]	Dec. 31, 2012 Robotics [Member] Intercompany Elimination [Member]	Dec. 31, 2014 Production Facilities [Member]	Dec. 31, 2013 Production Facilities [Member]	Dec. 31, 2012 Production Facilities [Member]	Dec. 31, 2013 Production Facilities [Member] Intercompany Elimination [Member]	Dec. 31, 2012 Production Facilities [Member] Intercompany Elimination [Member]	Dec. 31, 2014 Subsea Construction [Member]	Dec. 31, 2013 Subsea Construction [Member]	Dec. 31, 2012 Subsea Construction [Member]	Dec. 31, 2013 Subsea Construction [Member] Intercompany Elimination [Member]	Dec. 31, 2012 Subsea Construction [Member] Intercompany Elimination [Member]	Dec. 31, 2014 Spoolbase Facility [Member]	Jun. 30, 2013 Caesar [Member]	Dec. 31, 2012 Caesar [Member]	Jul. 31, 2013 Express [Member]	Dec. 31, 2012 Intrepid Vessel [Member]	Dec. 31, 2014 Intercompany Elimination [Member]	Dec. 31, 2013 Intercompany Elimination [Member]	Dec. 31, 2012 Intercompany Elimination [Member]	Dec. 31, 2014 Corporate And Eliminations [Member]	Dec. 31, 2013 Corporate And Eliminations [Member]	Dec. 31, 2012 Corporate And Eliminations [Member]	Dec. 31, 2014 Corporate [Member]	Dec. 31, 2013 Corporate [Member]	Dec. 31, 2012 Corporate [Member]	Dec. 31, 2012 Discontinued Operations [Member]
Segment Reporting Information [Line Items]
Revenues	$ 207,160,000	$ 340,837,000	$ 305,587,000	$ 253,572,000	$ 226,837,000	$ 220,117,000	$ 232,178,000	$ 197,429,000	$ 1,107,156,000	$ 876,561,000	$ 846,109,000	$ (74,450,000)	$ (68,607,000)	$ (133,775,000)	$ 667,849,000	$ 452,452,000	$ 378,546,000	$ (29,875,000)	$ (22,448,000)	$ (36,781,000)	$ 420,224,000	$ 333,246,000	$ 328,726,000	$ (44,575,000)	$ (41,169,000)	$ (46,465,000)	$ 93,175,000	$ 88,149,000	$ 80,091,000	$ (4,673,000)	$ (46,057,000)	$ 358,000	$ 71,321,000	$ 192,521,000	$ (317,000)	$ (4,472,000)						$ (74,450,000)	$ (68,607,000)	$ (133,775,000)
Income (loss) from operations									261,756,000	179,034,000	(68,483,000)				204,810,000	131,840,000	85,482,000				68,329,000	44,132,000	55,678,000				41,138,000	49,778,000	40,082,000			10,923,000	33,685,000	(148,862,000)								(921,000)	(3,360,000)	(7,878,000)				(62,523,000)	(77,041,000)	(92,985,000)
Net interest expense and other									114,000	38,411,000	65,949,000				(6,915,000)	(217,000)	2,152,000				7,304,000	(210,000)	(1,203,000)				384,000	380,000	365,000			(278,000)	480,000	(247,000)											(381,000)	37,978,000	64,882,000
Equity in earnings of investments									879,000	2,965,000	8,434,000
Income (loss) before income taxes									262,521,000	143,588,000	(125,998,000)				211,725,000	132,057,000	83,205,000				61,025,000	44,342,000	56,881,000				41,633,000	52,363,000	48,276,000			11,201,000	33,205,000	(148,615,000)											(63,063,000)	(118,379,000)	(165,745,000)
Provision for income taxes									66,971,000	31,612,000	(59,158,000)				50,102,000	26,718,000	15,400,000				21,612,000	15,530,000	20,222,000				14,395,000	17,233,000	15,784,000			3,881,000	11,655,000	(51,329,000)											(23,019,000)	(39,524,000)	(59,235,000)
Total assets	2,700,698,000				2,544,280,000				2,700,698,000	2,544,280,000	3,386,580,000				1,470,349,000	1,245,229,000	936,926,000				299,701,000	282,373,000	258,117,000				459,427,000	495,829,000	504,828,000			27,547,000	38,054,000	303,479,000														443,674,000	482,795,000	483,003,000	900,227,000
Capital expenditures									336,912,000	324,426,000	323,039,000				283,635,000	283,132,000	274,451,000				51,348,000	39,655,000	44,500,000				869,000	1,252,000	823,000																			1,060,000	387,000	3,265,000
Depreciation and amortization									109,345,000	98,535,000	97,201,000				57,570,000	44,619,000	37,736,000				24,478,000	22,263,000	19,933,000				21,278,000	17,193,000	16,828,000				8,651,000	19,773,000											6,019,000	5,809,000	2,931,000
Gain (loss) on disposition of assets, net									10,240,000	14,727,000	(13,476,000)																										10,500,000	(1,100,000)		15,600,000
Asset impairment																																							157,800,000		14,600,000
Other income - oil and gas									16,931,000	6,581,000
Proceeds from insurance reimbursement									$ 7,200,000

Business Segment Information (Summary Of Intercompany Segment Revenues) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Net revenues	$ (207,160)	$ (340,837)	$ (305,587)	$ (253,572)	$ (226,837)	$ (220,117)	$ (232,178)	$ (197,429)	$ (1,107,156)	$ (876,561)	$ (846,109)
Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Net revenues									74,450	68,607	133,775
Well Intervention [Member]
Segment Reporting Information [Line Items]
Net revenues									(667,849)	(452,452)	(378,546)
Well Intervention [Member] \| Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Net revenues									29,875	22,448	36,781
Robotics [Member]
Segment Reporting Information [Line Items]
Net revenues									(420,224)	(333,246)	(328,726)
Robotics [Member] \| Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Net revenues									44,575	41,169	46,465
Production Facilities [Member]
Segment Reporting Information [Line Items]
Net revenues									(93,175)	(88,149)	(80,091)
Production Facilities [Member] \| Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Net revenues										4,673	46,057
Subsea Construction [Member]
Segment Reporting Information [Line Items]
Net revenues									(358)	(71,321)	(192,521)
Subsea Construction [Member] \| Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Net revenues										317	4,472
Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Net revenues									$ 74,450	$ 68,607	$ 133,775

Business Segment Information (Intercompany Segment Gross Profit (Loss)) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Gross profit	$ (32,805)	$ (126,247)	$ (109,138)	$ (75,846)	$ (71,164)	$ (69,457)	$ (67,497)	$ (52,567)	$ (344,036)	$ (260,685)	$ (49,915)
Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Gross profit (loss) with other operating segments of same entity									921	3,360	7,878
Well Intervention [Member] \| Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Gross profit (loss) with other operating segments of same entity									(323)	(141)	6,203
Robotics [Member] \| Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Gross profit (loss) with other operating segments of same entity									1,419	3,518	180
Production Facilities [Member] \| Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Gross profit (loss) with other operating segments of same entity									(175)	(175)	(175)
Subsea Construction [Member] \| Intercompany Elimination [Member]
Segment Reporting Information [Line Items]
Gross profit (loss) with other operating segments of same entity										$ 158	$ 1,670

Business Segment Information (Revenue By Geographical Region) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Total net revenues	$ 207,160	$ 340,837	$ 305,587	$ 253,572	$ 226,837	$ 220,117	$ 232,178	$ 197,429	$ 1,107,156	$ 876,561	$ 846,109
United States [Member]
Segment Reporting Information [Line Items]
Total net revenues									403,994	345,525	281,308
North Sea [Member]
Segment Reporting Information [Line Items]
Total net revenues									504,016	403,816	345,074
North Sea [Member] \| United Kingdom [Member]
Segment Reporting Information [Line Items]
Total net revenues									362,700	327,100	283,100
Other [Member]
Segment Reporting Information [Line Items]
Total net revenues									$ 199,146	$ 127,220	$ 219,727

Business Segment Information (Property Plant And Equipment Net Of Depreciation By Geographic Region) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Property and equipment, net	$ 1,735,384	$ 1,532,217	$ 1,485,875
United States [Member]
Segment Reporting Information [Line Items]
Property and equipment, net	913,422	1,119,075	1,180,586
United Kingdom [Member]
Segment Reporting Information [Line Items]
Property and equipment, net	355,996	336,317	304,062
Luxembourg [Member]
Segment Reporting Information [Line Items]
Property and equipment, net	465,875	76,749
Other [Member]
Segment Reporting Information [Line Items]
Property and equipment, net	$ 91	$ 76	$ 1,227

Oil And Gas Properties (Narrative) (Details) (USD $) In Millions, unless otherwise specified	1 Months Ended	12 Months Ended				12 Months Ended
	Feb. 28, 2013	Dec. 31, 2014	Dec. 31, 2013 Camelot Field [Member]	Dec. 31, 2012 Camelot Field [Member]	Dec. 31, 2014 Camelot Field [Member]	Dec. 31, 2013 Gulf Of Mexico Oil And Gas Properties [Member]
Oil And Gas Properties [Line Items]
Proceeds from divestiture of business	$ 624
Asset retirement obligation			1.1	2.9	0.6
Asset retirement obligation revision of estimate			1.6	15.5
Asset retirement obligation, cash paid to settle						5.2
Proceeds from insurance reimbursement		$ 7.2

Oil and Gas Properties (Income (Loss) From Discontinued Operations) (Details) (USD $)	3 Months Ended			12 Months Ended
	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income from discontinued operations, net of tax	$ 44,000	$ (29,000)	$ 1,058,000	$ 1,073,000	$ 23,684,000
Oil and gas property impairments					138,600,000
Energy Resource Technology GOM, Inc [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues				48,847,000	557,231,000
Production (lifting) costs				16,017,000	164,663,000
Hurricane repair expense					662,000
Exploration expense				3,514,000	3,295,000
Depreciation, depletion, amortization and accretion				1,226,000	158,284,000
Proved property impairment and abandonment				(152,000)	151,045,000
Loss on sale of oil and gas properties					1,714,000
Hedge ineffectiveness and non-hedge gain on commodity derivative contracts					(5,550,000)
Selling, general and administrative expense				1,229,000	17,823,000
Net interest expense and other				2,732,000	28,191,000
Total costs				24,566,000	520,127,000
Pretax income from discontinued operations				24,281,000	37,104,000
Income tax provision				8,499,000	13,420,000
Income from operations of discontinued operations				15,782,000	23,684,000
Loss on sale of business, net of tax				(14,709,000)
Income from discontinued operations, net of tax				1,073,000	23,684,000
Net interest expense				$ 2,700,000	$ 27,700,000

Allowance Accounts (Schedule Of Allowance Accounts) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Allowance for Doubtful Accounts [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Deductions		$ 4,000
Allowance for Doubtful Accounts [Member] \| Helix [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance, Beginning Balance	2,234	5,152	4,000
Additions	5,331	2,236	1,257
Deductions	(2,830)	(5,154)	(105)
Valuation Allowances and Reserves, Balance, Ending Balance	4,735	2,234	5,152
Valuation Allowance of Deferred Tax Assets [Member] \| Helix [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Valuation Allowances and Reserves, Balance, Beginning Balance	22,860	16,391	14,310
Additions	216	6,469	2,081
Valuation Allowances and Reserves, Balance, Ending Balance	23,076	22,860	16,391
WOSEA [Member] \| Valuation Allowance of Deferred Tax Assets [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Additions		6,500	2,000
Oil And Gas Operations In United Kingdom [Member] \| Valuation Allowance of Deferred Tax Assets [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Additions			$ 100

Derivative Instruments And Hedging Activities (Narrative) (Details) In Millions, unless otherwise specified	12 Months Ended	1 Months Ended
	Dec. 31, 2014 USD ($)	Feb. 28, 2013 Oil And Gas Commodity Contracts [Member] USD ($)	Feb. 28, 2013 Interest Rate Swaps [Member] USD ($)	Sep. 30, 2013 Interest Rate Swaps [Member] USD ($)	Feb. 28, 2013 Grand Canyon I I I [Member] USD ($)	Feb. 28, 2013 Grand Canyon I I I [Member] NOK	Feb. 28, 2013 Grand Canyon I I [Member] USD ($)	Feb. 28, 2013 Grand Canyon I I [Member] NOK	Jan. 31, 2013 Grand Canyon [Member] USD ($)	Jan. 31, 2013 Grand Canyon [Member] NOK
Derivative [Line Items]
Derivative cash settlement		$ 22.5	$ 0.6
Notional amount of derivative				148.1	98.8	595.0	100.4	594.7	104.6	591.3
Loss on foreign currency cash flow hedge ineffectiveness	1.7
Cash flow hedge loss to be reclassified within twelve months	$ 7.8

Derivative Instruments And Hedging Activities (Derivatives Designated As Hedging Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Asset derivatives designated as hedging instruments	$ 369	$ 446
Liability derivatives designated as hedging instruments	50,989	15,817
Other Assets, Net [Member] \| Interest Rate Swaps [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives designated as hedging instruments	369	446
Accrued Liabilities [Member] \| Interest Rate Swaps [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives designated as hedging instruments	561	746
Accrued Liabilities [Member] \| Foreign Exchange Contracts [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives designated as hedging instruments	12,661	1,905
Other Liabilities [Member] \| Foreign Exchange Contracts [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives designated as hedging instruments	$ 37,767	$ 13,166

Derivative Instruments And Hedging Activities (Impact Of Derivative Instruments On Accumulated Comprehensive Income (Loss)) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	$ (22,100)	$ (9,991)	$ (12,941)
Oil And Gas Commodity Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)			(12,860)
Foreign Exchange Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	(22,170)	(9,796)
Interest Rate Swaps [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	$ 70	$ (195)	$ (81)

Derivative Instruments And Hedging Activities (Gain (Loss) Reclassified From Accumulated OCI Into Income) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Earnings (Effective Portion)	$ (3,365)	$ (1,476)	$ 2,661
Oil And Gas Commodity Contracts [Member] \| Income From Discontinued Operations Net Of Tax [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Earnings (Effective Portion)			3,184
Interest Rate Swaps [Member] \| Net Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Earnings (Effective Portion)	(858)	(152)	(523)
Foreign Exchange Contracts [Member] \| Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated OCI into Earnings (Effective Portion)	$ (2,507)	$ (1,324)

Derivative Instruments And Hedging Activities (Impact Of Non Designated Derivative Instruments On Income Statement) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Earnings on Derivatives	$ 7	$ (14,829)	$ (5,113)
Oil And Gas Commodity Contracts [Member] \| Income From Discontinued Operations Net Of Tax [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Earnings on Derivatives			5,550
Oil And Gas Commodity Contracts [Member] \| Non Hedge Loss On Commodity Derivative Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Earnings on Derivatives		(14,113)	(10,507)
Interest Rate Swaps [Member] \| Other Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Earnings on Derivatives		(86)	(567)
Foreign Exchange Contracts [Member] \| Other Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Earnings on Derivatives	$ 7	$ (630)	$ 411

Quarterly Financial Information (Summary Of Consolidated Quarterly Financial Information) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quarterly Financial Information [Line Items]
Net revenues	$ 207,160	$ 340,837	$ 305,587	$ 253,572	$ 226,837	$ 220,117	$ 232,178	$ 197,429	$ 1,107,156	$ 876,561	$ 846,109
Gross profit	32,805	126,247	109,138	75,846	71,164	69,457	67,497	52,567	344,036	260,685	49,915
Net income applicable to Helix:
Net income from continuing operations					36,503	44,549	27,240	557	195,047	108,849	(70,018)
Income (loss) from discontinued operations						44	(29)	1,058		1,073	23,684
Net income (loss) applicable to Helix	7,960	75,586	57,782	53,719	36,503	44,593	27,211	1,615	195,047	109,922	(46,334)
Basic earnings per common share:
Continuing operations					$ 0.35	$ 0.42	$ 0.26	$ 0.01	$ 1.85	$ 1.03	$ (0.67)
Discontinued operations								$ 0.01		$ 0.01	$ 0.23
Net income (loss) per common share	$ 0.08	$ 0.72	$ 0.55	$ 0.51	$ 0.35	$ 0.42	$ 0.26	$ 0.02	$ 1.85	$ 1.04	$ (0.44)
Diluted earnings (loss) per common share:
Continuing operations					$ 0.35	$ 0.42	$ 0.26	$ 0.01	$ 1.85	$ 1.03	$ (0.67)
Discontinued operations								$ 0.01		$ 0.01	$ 0.23
Net income (loss) per common share	$ 0.08	$ 0.71	$ 0.55	$ 0.51	$ 0.35	$ 0.42	$ 0.26	$ 0.02	$ 1.85	$ 1.04	$ (0.44)
Discontinued Operations [Member]
Quarterly Financial Information [Line Items]
Net revenues								48,800
Gross profit								$ 28,200

Summary Of Significant Accounting Policies (Related Party Transactions - Narrative) (Details) (OKCD [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
OKCD [Member]
Partnership interests	85.00%
Related party payment		$ 0.6

Derivative Instruments And Hedging Activities (Derivatives Not Designated As Hedging Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2013
Derivative [Line Items]
Asset derivatives not designated as hedging instruments	$ 69
Other Current Assets [Member] \| Foreign Exchange Contracts [Member]
Derivative [Line Items]
Asset derivatives not designated as hedging instruments	$ 69