UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
Form 10-Q
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☑ | | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended September 30, 2019March 31, 2020
or
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☐ | | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from__________ to__________
Commission File Number: 001-32936
HELIX ENERGY SOLUTIONS GROUP, INC.
(Exact name of registrant as specified in its charter)
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| | | |
Minnesota | | 95-3409686 |
(State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification No.) |
| | | |
3505 West Sam Houston Parkway North | | |
Suite 400 | | |
Houston | Texas | | 77043 |
(Address of principal executive offices) | | (Zip Code) |
(281) 618–0400
(Registrant's telephone number, including area code)
NOT APPLICABLE
(Former name, former address and former fiscal year, if changed since last report)
Securities registered pursuant to Section 12(b) of the Act:
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| | | | |
Title of each class | | Trading Symbol(s) | | Name of each exchange on which registered |
Common Stock | | HLX | | New York Stock Exchange |
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☑ Yes ☐ No
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). ☑ Yes ☐ No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
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| | | | | | | | |
Large accelerated filer | ☑ | Accelerated filer ☐ | Non-accelerated filer ☐ | Smaller reporting company | ☐ | Emerging growth company | ☐ |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☑ No
As of October 18, 2019, 148,809,467April 17, 2020, 150,005,466 shares of common stock were outstanding.
TABLE OF CONTENTS
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PART I. | | FINANCIAL INFORMATION | PAGE |
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Item 1. | | Financial Statements: | |
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Item 2. | | | |
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Item 3. | | | |
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Item 4. | | | |
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PART II. | | OTHER INFORMATION | |
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Item 1. | | | |
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Item 2. | | | |
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Item 6. | | | |
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PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(in thousands)
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| (Unaudited) | | | (Unaudited) | | |
ASSETS | Current assets: | | | | | | |
Cash and cash equivalents | $ | 286,340 |
| | $ | 279,459 |
| $ | 159,351 |
| | $ | 208,431 |
|
Accounts receivable: | | | | |
Trade, net of allowance for uncollectible accounts of $0 | 91,707 |
| | 67,932 |
| |
Unbilled and other | 72,548 |
| | 51,943 |
| |
Restricted cash | | 52,374 |
| | 54,130 |
|
Accounts receivable, net of allowance for credit losses of $1,371 and $0, respectively | | 147,120 |
| | 125,457 |
|
Other current assets | 61,751 |
| | 51,594 |
| 71,755 |
| | 50,450 |
|
Total current assets | 512,346 |
| | 450,928 |
| 430,600 |
| | 438,468 |
|
Property and equipment | 2,819,932 |
| | 2,785,778 |
| 2,880,657 |
| | 2,922,274 |
|
Less accumulated depreciation | (1,022,138 | ) | | (959,033 | ) | (1,070,733 | ) | | (1,049,637 | ) |
Property and equipment, net | 1,797,794 |
| | 1,826,745 |
| 1,809,924 |
| | 1,872,637 |
|
Operating lease right-of-use assets | 213,048 |
| | — |
| 187,553 |
| | 201,118 |
|
Other assets, net | 90,323 |
| | 70,057 |
| 86,074 |
| | 84,508 |
|
Total assets | $ | 2,613,511 |
| | $ | 2,347,730 |
| $ | 2,514,151 |
| | $ | 2,596,731 |
|
| | | | | | |
LIABILITIES AND SHAREHOLDERS' EQUITY | Current liabilities: | | | | | | |
Accounts payable | $ | 79,122 |
| | $ | 54,813 |
| $ | 90,425 |
| | $ | 69,055 |
|
Accrued liabilities | 71,982 |
| | 85,594 |
| 45,227 |
| | 62,389 |
|
Income tax payable | — |
| | 3,829 |
| |
Current maturities of long-term debt | 108,468 |
| | 47,252 |
| 90,837 |
| | 99,731 |
|
Current operating lease liabilities | 52,840 |
| | — |
| 53,063 |
| | 53,785 |
|
Total current liabilities | 312,412 |
| | 191,488 |
| 279,552 |
| | 284,960 |
|
Long-term debt | 304,932 |
| | 393,063 |
| 303,584 |
| | 306,122 |
|
Operating lease liabilities | 164,761 |
| | — |
| 137,411 |
| | 151,827 |
|
Deferred tax liabilities | 110,118 |
| | 105,862 |
| 104,930 |
| | 112,132 |
|
Other non-current liabilities | 39,008 |
| | 39,538 |
| 36,286 |
| | 38,644 |
|
Total liabilities | 931,231 |
| | 729,951 |
| 861,763 |
| | 893,685 |
|
Redeemable noncontrolling interests | 3,257 |
| | — |
| 3,323 |
| | 3,455 |
|
Shareholders’ equity: | | | | | | |
Common stock, no par, 240,000 shares authorized, 148,802 and 148,203 shares issued, respectively | 1,316,805 |
| | 1,308,709 |
| |
Common stock, no par, 240,000 shares authorized, 149,962 and 148,888 shares issued, respectively | | 1,316,401 |
| | 1,318,961 |
|
Retained earnings | 437,418 |
| | 383,034 |
| 430,726 |
| | 445,370 |
|
Accumulated other comprehensive loss | (75,200 | ) | | (73,964 | ) | (98,062 | ) | | (64,740 | ) |
Total shareholders’ equity | 1,679,023 |
| | 1,617,779 |
| 1,649,065 |
| | 1,699,591 |
|
Total liabilities, redeemable noncontrolling interests and shareholders’ equity | $ | 2,613,511 |
| | $ | 2,347,730 |
| $ | 2,514,151 |
| | $ | 2,596,731 |
|
The accompanying notes are an integral part of these condensed consolidated financial statements.
HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)
(in thousands, except per share amounts)
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 | 2020 | | 2019 |
| | | | | | | | | | |
Net revenues | $ | 212,609 |
| | $ | 212,575 |
| | $ | 581,160 |
| | $ | 581,462 |
| $ | 181,021 |
| | $ | 166,823 |
|
Cost of sales | 157,535 |
| | 160,582 |
| | 469,898 |
| | 473,589 |
| 179,011 |
| | 150,569 |
|
Gross profit | 55,074 |
| | 51,993 |
| | 111,262 |
| | 107,873 |
| 2,010 |
| | 16,254 |
|
Gain on disposition of assets, net | — |
| | 146 |
| | — |
| | 146 |
| |
Goodwill impairment | | (6,689 | ) | | — |
|
Selling, general and administrative expenses | (16,076 | ) | | (20,762 | ) | | (48,923 | ) | | (52,986 | ) | (16,348 | ) | | (15,985 | ) |
Income from operations | 38,998 |
| | 31,377 |
| | 62,339 |
| | 55,033 |
| |
Income (loss) from operations | | (21,027 | ) | | 269 |
|
Equity in losses of investment | (13 | ) | | (107 | ) | | (82 | ) | | (378 | ) | (20 | ) | | (40 | ) |
Net interest expense | (1,901 | ) | | (3,249 | ) | | (6,204 | ) | | (10,744 | ) | (5,746 | ) | | (2,098 | ) |
Loss on extinguishment of long-term debt | — |
| | (2 | ) | | (18 | ) | | (1,183 | ) | |
Other expense, net | (2,285 | ) | | (709 | ) | | (2,430 | ) | | (3,225 | ) | |
Other income (expense), net | | (10,427 | ) | | 1,166 |
|
Royalty income and other | 362 |
| | 652 |
| | 2,897 |
| | 4,068 |
| 2,199 |
| | 2,345 |
|
Income before income taxes | 35,161 |
| | 27,962 |
| | 56,502 |
| | 43,571 |
| |
Income tax provision | 3,539 |
| | 841 |
| | 6,739 |
| | 1,226 |
| |
Net income | 31,622 |
| | 27,121 |
| | 49,763 |
| | 42,345 |
| |
Income (loss) before income taxes | | (35,021 | ) | | 1,642 |
|
Income tax provision (benefit) | | (21,093 | ) | | 324 |
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Net income (loss) | | (13,928 | ) | | 1,318 |
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Net loss attributable to redeemable noncontrolling interests | (73 | ) | | — |
| | (104 | ) | | — |
| (1,990 | ) | | — |
|
Net income attributable to common shareholders | $ | 31,695 |
| | $ | 27,121 |
| | $ | 49,867 |
| | $ | 42,345 |
| |
Net income (loss) attributable to common shareholders | | $ | (11,938 | ) | | $ | 1,318 |
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| | | | | | | | | | |
Earnings per share of common stock: | | | | | | | | |
Earnings (loss) per share of common stock: | | | | |
Basic | $ | 0.21 |
| | $ | 0.18 |
| | $ | 0.33 |
| | $ | 0.29 |
| $ | (0.09 | ) | | $ | 0.01 |
|
Diluted | $ | 0.21 |
| | $ | 0.18 |
| | $ | 0.33 |
| | $ | 0.29 |
| $ | (0.09 | ) | | $ | 0.01 |
|
| | | | | | | | | | |
Weighted average common shares outstanding: | | | | | | | | | | |
Basic | 147,575 |
| | 146,700 |
| | 147,506 |
| | 146,679 |
| 148,863 |
| | 147,421 |
|
Diluted | 148,354 |
| | 146,964 |
| | 148,086 |
| | 146,761 |
| 148,863 |
| | 147,751 |
|
The accompanying notes are an integral part of these condensed consolidated financial statements.
HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(UNAUDITED)
(in thousands)
|
| | | | | | | | | | | | | | | |
| Three Months Ended September 30, | | Nine Months Ended September 30, |
| 2019 | | 2018 | | 2019 | | 2018 |
| | | | | | | |
Net income | $ | 31,622 |
| | $ | 27,121 |
| | $ | 49,763 |
| | $ | 42,345 |
|
Other comprehensive loss, net of tax: | | | | | | | |
Net unrealized gain (loss) on hedges arising during the period | (274 | ) | | (88 | ) | | (701 | ) | | 839 |
|
Reclassifications to net income | 1,046 |
| | 1,799 |
| | 4,867 |
| | 5,233 |
|
Income taxes on hedges | (156 | ) | | (357 | ) | | (838 | ) | | (1,298 | ) |
Net change in hedges, net of tax | 616 |
| | 1,354 |
| | 3,328 |
| | 4,774 |
|
Unrealized loss on note receivable arising during the period | — |
| | — |
| | — |
| | (629 | ) |
Income taxes on note receivable | — |
| | — |
| | — |
| | 132 |
|
Unrealized loss on note receivable, net of tax | — |
| | — |
| | — |
| | (497 | ) |
Foreign currency translation loss | (4,301 | ) | | (1,421 | ) | | (4,564 | ) | | (4,277 | ) |
Other comprehensive loss, net of tax | (3,685 | ) | | (67 | ) | | (1,236 | ) | | — |
|
Comprehensive income | 27,937 |
| | 27,054 |
| | 48,527 |
| | 42,345 |
|
Less comprehensive loss attributable to redeemable noncontrolling interests: | | | | | | | |
Net loss | (73 | ) | | — |
| | (104 | ) | | — |
|
Foreign currency translation loss | (78 | ) | | — |
| | (78 | ) | | — |
|
Comprehensive loss attributable to redeemable noncontrolling interests | (151 | ) | | — |
| | (182 | ) | | — |
|
Comprehensive income attributable to common shareholders | $ | 28,088 |
| | $ | 27,054 |
| | $ | 48,709 |
| | $ | 42,345 |
|
|
| | | | | | | |
| Three Months Ended March 31, |
| 2020 | | 2019 |
| | | |
Net income (loss) | $ | (13,928 | ) | | $ | 1,318 |
|
Other comprehensive income (loss), net of tax: | | | |
Net unrealized loss on hedges arising during the period | (96 | ) | | (149 | ) |
Reclassifications to net (income) loss | 427 |
| | 1,846 |
|
Income taxes on hedges | (66 | ) | | (342 | ) |
Net change in hedges, net of tax | 265 |
| | 1,355 |
|
Foreign currency translation gain (loss) | (33,587 | ) | | 2,802 |
|
Other comprehensive income (loss), net of tax | (33,322 | ) | | 4,157 |
|
Comprehensive income (loss) | (47,250 | ) | | 5,475 |
|
Less comprehensive loss attributable to redeemable noncontrolling interests: | | | |
Net loss | (1,990 | ) | | — |
|
Foreign currency translation loss | (228 | ) | | — |
|
Comprehensive loss attributable to redeemable noncontrolling interests | (2,218 | ) | | — |
|
Comprehensive income (loss) attributable to common shareholders | $ | (45,032 | ) | | $ | 5,475 |
|
The accompanying notes are an integral part of these condensed consolidated financial statements.
HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY
(UNAUDITED)
(in thousands)
| | | Common Stock | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total Shareholders’ Equity | | Redeemable Noncontrolling Interests | Common Stock | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total Shareholders’ Equity | | Redeemable Noncontrolling Interests |
| Shares | | Amount | | Shares | | Amount | |
| | | | | | | | | | | | | | | | | | | | | | |
Balance, June 30, 2019 | 148,759 |
| | $ | 1,314,163 |
| | $ | 405,748 |
| | $ | (71,515 | ) | | $ | 1,648,396 |
| | $ | 3,383 |
| |
Net income (loss) | — |
| | — |
| | 31,695 |
| | — |
| | 31,695 |
| | (73 | ) | |
Balance, December 31, 2019 | | 148,888 |
| | $ | 1,318,961 |
| | $ | 445,370 |
| | $ | (64,740 | ) | | $ | 1,699,591 |
| | $ | 3,455 |
|
Net loss | | — |
| | — |
| | (11,938 | ) | | — |
| | (11,938 | ) | | (1,990 | ) |
Expected credit losses recognized in retained earnings upon adoption of ASU 2016-13 | | — |
| | — |
| | (620 | ) | | — |
| | (620 | ) | | — |
|
Foreign currency translation adjustments | — |
| | — |
| | — |
| | (4,301 | ) | | (4,301 | ) | | (78 | ) | — |
| | — |
| | — |
| | (33,587 | ) | | (33,587 | ) | | (228 | ) |
Unrealized gain on hedges, net of tax | — |
| | — |
| | — |
| | 616 |
| | 616 |
| | — |
| — |
| | — |
| | — |
| | 265 |
| | 265 |
| | — |
|
Accretion of redeemable noncontrolling interests | — |
| | — |
| | (25 | ) | | — |
| | (25 | ) | | 25 |
| — |
| | — |
| | (2,086 | ) | | — |
| | (2,086 | ) | | 2,086 |
|
Activity in company stock plans, net and other | 43 |
| | 214 |
| | — |
| | — |
| | 214 |
| | — |
| 1,074 |
| | (4,730 | ) | | — |
| | — |
| | (4,730 | ) | | — |
|
Share-based compensation | — |
| | 2,428 |
| | — |
| | — |
| | 2,428 |
| | — |
| — |
| | 2,170 |
| | — |
| | — |
| | 2,170 |
| | — |
|
Balance, September 30, 2019 | 148,802 |
| | $ | 1,316,805 |
| | $ | 437,418 |
| | $ | (75,200 | ) | | $ | 1,679,023 |
| | $ | 3,257 |
| |
Balance, March 31, 2020 | | 149,962 |
| | $ | 1,316,401 |
| | $ | 430,726 |
| | $ | (98,062 | ) | | $ | 1,649,065 |
| | $ | 3,323 |
|
| | | Common Stock | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total Shareholders’ Equity | | Redeemable Noncontrolling Interests | Common Stock | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total Shareholders’ Equity | | Redeemable Noncontrolling Interests |
| Shares | | Amount | | Shares | | Amount | |
| | | | | | | | | | | | | | | | | | | | | | |
Balance, June 30, 2018 | 148,107 |
| | $ | 1,303,984 |
| | $ | 369,659 |
| | $ | (71,249 | ) | | $ | 1,602,394 |
| | $ | — |
| |
Balance, December 31, 2018 | | 148,203 |
| | $ | 1,308,709 |
| | $ | 383,034 |
| | $ | (73,964 | ) | | $ | 1,617,779 |
| | $ | — |
|
Net income | — |
| | — |
| | 27,121 |
| | — |
| | 27,121 |
| | — |
| — |
| | — |
| | 1,318 |
| | — |
| | 1,318 |
| | — |
|
Reclassification of deferred gain from sale and leaseback transaction to retained earnings | | — |
| | — |
| | 4,560 |
| | — |
| | 4,560 |
| | — |
|
Foreign currency translation adjustments | — |
| | — |
| | — |
| | (1,421 | ) | | (1,421 | ) | | — |
| — |
| | — |
| | — |
| | 2,802 |
| | 2,802 |
| | — |
|
Unrealized gain on hedges, net of tax | — |
| | — |
| | — |
| | 1,354 |
| | 1,354 |
| | — |
| — |
| | — |
| | — |
| | 1,355 |
| | 1,355 |
| | — |
|
Equity component of debt discount on convertible senior notes | — |
| | (2 | ) | | — |
| | — |
| | (2 | ) | | — |
| |
Activity in company stock plans, net and other | 40 |
| | 213 |
| | — |
| | — |
| | 213 |
| | — |
| 582 |
| | (659 | ) | | — |
| | — |
| | (659 | ) | | — |
|
Share-based compensation | — |
| | 2,509 |
| | — |
| | — |
| | 2,509 |
| | — |
| — |
| | 2,688 |
| | — |
| | — |
| | 2,688 |
| | — |
|
Balance, September 30, 2018 | 148,147 |
| | $ | 1,306,703 |
| | $ | 396,781 |
| | $ | (71,316 | ) | | $ | 1,632,168 |
| | $ | — |
| |
Balance, March 31, 2019 | | 148,785 |
| | $ | 1,310,738 |
| | $ | 388,912 |
| | $ | (69,807 | ) | | $ | 1,629,843 |
| | $ | — |
|
The accompanying notes are an integral part of these condensed consolidated financial statements.
HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITYCASH FLOWS
(UNAUDITED)
(in thousands)
|
| | | | | | | | | | | | | | | | | | | | | | |
| Common Stock | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total Shareholders’ Equity | | Redeemable Noncontrolling Interests |
| Shares | | Amount | | | | |
| | | | | | | | | | | |
Balance, December 31, 2018 | 148,203 |
| | $ | 1,308,709 |
| | $ | 383,034 |
| | $ | (73,964 | ) | | $ | 1,617,779 |
| | $ | — |
|
Net income (loss) | — |
| | — |
| | 49,867 |
| | — |
| | 49,867 |
| | (104 | ) |
Reclassification of deferred gain from sale and leaseback transaction to retained earnings | — |
| | — |
| | 4,560 |
| | — |
| | 4,560 |
| | — |
|
Foreign currency translation adjustments | — |
| | — |
| | — |
| | (4,564 | ) | | (4,564 | ) | | (78 | ) |
Unrealized gain on hedges, net of tax | — |
| | — |
| | — |
| | 3,328 |
| | 3,328 |
| | — |
|
Issuance of redeemable noncontrolling interests | — |
| | — |
| | — |
| | — |
| | — |
| | 3,396 |
|
Accretion of redeemable noncontrolling interests | — |
| | — |
| | (43 | ) | | — |
| | (43 | ) | | 43 |
|
Activity in company stock plans, net and other | 599 |
| | (765 | ) | | — |
| | — |
| | (765 | ) | | — |
|
Share-based compensation | — |
| | 8,861 |
| | — |
| | — |
| | 8,861 |
| | — |
|
Balance, September 30, 2019 | 148,802 |
| | $ | 1,316,805 |
| | $ | 437,418 |
| | $ | (75,200 | ) | | $ | 1,679,023 |
| | $ | 3,257 |
|
|
| | | | | | | | | | | | | | | | | | | | | | |
| Common Stock | | Retained Earnings | | Accumulated Other Comprehensive Loss | | Total Shareholders’ Equity | | Redeemable Noncontrolling Interests |
| Shares | | Amount | | | | |
| | | | | | | | | | | |
Balance, December 31, 2017 | 147,740 |
| | $ | 1,284,274 |
| | $ | 352,906 |
| | $ | (69,787 | ) | | $ | 1,567,393 |
| | $ | — |
|
Net income | — |
| | — |
| | 42,345 |
| | — |
| | 42,345 |
| | — |
|
Reclassification of stranded tax effect to retained earnings | — |
| | — |
| | 1,530 |
| | (1,530 | ) | | — |
| | — |
|
Foreign currency translation adjustments | — |
| | — |
| | — |
| | (4,277 | ) | | (4,277 | ) | | — |
|
Unrealized gain on hedges, net of tax | — |
| | — |
| | — |
| | 4,774 |
| | 4,774 |
| | — |
|
Unrealized loss on note receivable, net of tax | — |
| | — |
| | — |
| | (497 | ) | | (497 | ) | | — |
|
Equity component of debt discount on convertible senior notes | — |
| | 15,411 |
| | — |
| | — |
| | 15,411 |
| | — |
|
Activity in company stock plans, net and other | 407 |
| | (438 | ) | | — |
| | — |
| | (438 | ) | | — |
|
Share-based compensation | — |
| | 7,456 |
| | — |
| | — |
| | 7,456 |
| | — |
|
Balance, September 30, 2018 | 148,147 |
| | $ | 1,306,703 |
| | $ | 396,781 |
| | $ | (71,316 | ) | | $ | 1,632,168 |
| | $ | — |
|
|
| | | | | | | |
| Three Months Ended March 31, |
| 2020 | | 2019 |
Cash flows from operating activities: | | | |
Net income (loss) | $ | (13,928 | ) | | $ | 1,318 |
|
Adjustments to reconcile net income (loss) to net cash used in operating activities: | | | |
Depreciation and amortization | 31,598 |
| | 28,509 |
|
Goodwill impairment | 6,689 |
| | — |
|
Amortization of debt discounts | 1,633 |
| | 1,513 |
|
Amortization of debt issuance costs | 833 |
| | 902 |
|
Share-based compensation | 2,259 |
| | 2,719 |
|
Deferred income taxes | (6,517 | ) | | (10 | ) |
Equity in losses of investment | 20 |
| | 40 |
|
Unrealized gain on derivative contracts, net | (601 | ) | | (829 | ) |
Unrealized foreign currency (gain) loss | 9,237 |
| | (1,128 | ) |
Changes in operating assets and liabilities: | | | |
Accounts receivable, net | (25,375 | ) | | (22,584 | ) |
Income tax receivable | (17,033 | ) | | (2,370 | ) |
Other current assets | (5,475 | ) | | (13,129 | ) |
Accounts payable and accrued liabilities | 15,543 |
| | (15,899 | ) |
Other, net | (16,105 | ) | | (13,298 | ) |
Net cash used in operating activities | (17,222 | ) | | (34,246 | ) |
| | | |
Cash flows from investing activities: | | | |
Capital expenditures | (12,389 | ) | | (11,655 | ) |
Proceeds from sale of assets | — |
| | 25 |
|
Other | — |
| | (326 | ) |
Net cash used in investing activities | (12,389 | ) | | (11,956 | ) |
| | | |
Cash flows from financing activities: | | | |
Repayment of term loans | (875 | ) | | (936 | ) |
Repayment of Nordea Q5000 Loan | (8,929 | ) | | (8,929 | ) |
Repayment of MARAD Debt | (3,556 | ) | | (3,387 | ) |
Debt issuance costs | (212 | ) | | (113 | ) |
Payments related to tax withholding for share-based compensation | (5,150 | ) | | (826 | ) |
Proceeds from issuance of ESPP shares | 331 |
| | 136 |
|
Net cash used in financing activities | (18,391 | ) | | (14,055 | ) |
| | | |
Effect of exchange rate changes on cash and cash equivalents and restricted cash | (2,834 | ) | | 821 |
|
Net decrease in cash and cash equivalents and restricted cash | (50,836 | ) | | (59,436 | ) |
Cash and cash equivalents and restricted cash: | | | |
Balance, beginning of year | 262,561 |
| | 279,459 |
|
Balance, end of period | $ | 211,725 |
| | $ | 220,023 |
|
The accompanying notes are an integral part of these condensed consolidated financial statements.
HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(UNAUDITED)
(in thousands)
|
| | | | | | | |
| Nine Months Ended September 30, |
| 2019 | | 2018 |
Cash flows from operating activities: | | | |
Net income | $ | 49,763 |
| | $ | 42,345 |
|
Adjustments to reconcile net income to net cash provided by operating activities: | | | |
Depreciation and amortization | 84,420 |
| | 83,339 |
|
Amortization of debt discounts | 4,642 |
| | 4,238 |
|
Amortization of debt issuance costs | 2,752 |
| | 2,703 |
|
Share-based compensation | 8,979 |
| | 7,569 |
|
Deferred income taxes | 2,347 |
| | (5,716 | ) |
Equity in losses of investment | 82 |
| | 378 |
|
Gain on disposition of assets, net | — |
| | (146 | ) |
Loss on extinguishment of long-term debt | 18 |
| | 1,183 |
|
Unrealized gain on derivative contracts, net | (2,351 | ) | | (2,289 | ) |
Changes in operating assets and liabilities, net of acquisitions: | | | |
Accounts receivable, net | (45,399 | ) | | (15,769 | ) |
Other current assets | 12,215 |
| | (5,662 | ) |
Income tax payable, net of income tax receivable | (3,143 | ) | | 2,963 |
|
Accounts payable and accrued liabilities | (14,765 | ) | | 6,968 |
|
Other, net | (9,683 | ) | | 28,723 |
|
Net cash provided by operating activities | 89,877 |
| | 150,827 |
|
| | | |
Cash flows from investing activities: | | | |
Capital expenditures | (45,636 | ) | | (55,431 | ) |
STL acquisition, net | (4,081 | ) | | — |
|
Proceeds from sale of assets | 2,550 |
| | 25 |
|
Net cash used in investing activities | (47,167 | ) | | (55,406 | ) |
| | | |
Cash flows from financing activities: | | | |
Issuance of Convertible Senior Notes due 2023 | — |
| | 125,000 |
|
Repurchase of Convertible Senior Notes due 2032 | — |
| | (60,365 | ) |
Proceeds from term loan | 35,000 |
| | — |
|
Repayment of term loan | (34,567 | ) | | (62,872 | ) |
Repayment of Nordea Q5000 Loan | (26,786 | ) | | (26,786 | ) |
Repayment of MARAD Debt | (6,858 | ) | | (6,532 | ) |
Debt issuance costs | (1,544 | ) | | (3,867 | ) |
Payments related to tax withholding for share-based compensation | (1,345 | ) | | (1,058 | ) |
Proceeds from issuance of ESPP shares | 462 |
| | 506 |
|
Net cash used in financing activities | (35,638 | ) | | (35,974 | ) |
| | | |
Effect of exchange rate changes on cash and cash equivalents | (191 | ) | | (947 | ) |
Net increase in cash and cash equivalents | 6,881 |
| | 58,500 |
|
Cash and cash equivalents: | | | |
Balance, beginning of year | 279,459 |
| | 266,592 |
|
Balance, end of period | $ | 286,340 |
| | $ | 325,092 |
|
The accompanying notes are an integral part of these condensed consolidated financial statements.
HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
Note 1 — Basis of Presentation and New Accounting Standards
The accompanying condensed consolidated financial statements include the accounts of Helix Energy Solutions Group, Inc. and its subsidiaries (collectively, Helix)“Helix”). Unless the context indicates otherwise, the terms “we,” “us” and “our” in this report refer collectively to Helix and its subsidiaries. All material intercompany accounts and transactions have been eliminated. These unaudited condensed consolidated financial statements have been prepared pursuant to instructions for the Quarterly Report on Form 10-Q required to be filed with the Securities and Exchange Commission (the “SEC”) and do not include all information and footnotes normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”).
The accompanying condensed consolidated financial statements have been prepared in conformity with GAAP in U.S. dollars and are consistent in all material respects with those applied in our 20182019 Annual Report on Form 10-K (“2018(our “2019 Form 10-K”) with the exception of the impact of adopting the new leasecredit loss accounting standard in 20192020 (see below). The preparation of these financial statements requires us to make estimates and judgments that affect the amounts reported in the financial statements and the related disclosures. Actual results may differ from our estimates. We have made all adjustments, which, unless otherwise disclosed, are of normal recurring nature, that we believe are necessary for a fair presentation of the condensed consolidated balance sheets, statements of operations, statements of comprehensive income and statements of cash flows, as applicable. The operating results for the three- and nine-month periodsthree-month period ended September 30, 2019March 31, 2020 are not necessarily indicative of the results that may be expected for the year ending December 31, 2019.2020. Our balance sheet as of December 31, 20182019 included herein has been derived from the audited balance sheet as of December 31, 20182019 included in our 20182019 Form 10-K. These unaudited condensed consolidated financial statements should be read in conjunction with the annual audited consolidated financial statements and notes thereto included in our 20182019 Form 10-K.
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.
COVID-19
In March 2020, the World Health Organization classified the outbreak of COVID-19 as a pandemic. The nature of COVID-19 led to worldwide shutdowns and halting of commercial and interpersonal activity, as governments around the world imposed regulations in efforts to control the spread of COVID-19 such as shelter-in-place orders, quarantines, executive orders and similar restrictions. As a result, the global economy has been marked by significant slowdown and uncertainty, which has led to a precipitous decline in oil prices in response to demand concerns, further exacerbated by the price war among members of the Organization of Petroleum Exporting Countries (“OPEC”) and other non-OPEC producer nations (collectively with OPEC members, “OPEC+”) during the first quarter 2020 and global storage considerations. The decline in oil prices has resulted in a significantly weaker outlook for oil and gas producers, who have begun to cut their capital and operating budgets. Our financial statements for the three-month period ended March 31, 2020 reflect the impact of these events and current market conditions, which include namely the recognition of goodwill impairment losses (Note 6) and tax benefits resulting from the U.S. Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”) (Note 8). The continued spread of COVID-19 or deterioration in oil prices could result in further adverse impact on our results of operations, cash flows and financial position, including further asset impairments.
New accounting standards adopted
In FebruaryJune 2016, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02, “Leases (Topic 842)” (“ASC 842”), which was updated by subsequent amendments. ASC 842 requires a lessee to recognize a lease right-of-use asset and related lease liability for most leases, including those classified as operating leases. ASC 842 also changes the definition of a lease and requires expanded quantitative and qualitative disclosures for both lessees and lessors. We adopted ASC 842 in the first quarter of 2019 using the modified retrospective method. We also elected the package of practical expedients permitted under the transition guidance that, among other things, allows companies to carry forward their historical lease classification. Our adoption of ASC 842 resulted in the recognition of operating lease liabilities of $259.0 million and corresponding right-of-use (“ROU”) assets of $253.4 million (net of existing prepaid/deferred rent balances) as of January 1, 2019. In addition, we reclassified the remaining deferred gain of $4.6 million (net of deferred taxes of $0.9 million) on a 2016 sale and leaseback transaction to retained earnings. Subsequent to adoption, leases in foreign currencies will generate foreign currency gains and losses, and we will no longer amortize the deferred gain from the aforementioned sale and leaseback transaction. Aside from these changes, ASC 842 is not expected to have a material impact on our net earnings or cash flows.
New accounting standards issued but not yet effective
In June 2016, the FASB issued ASU No. 2016-13, “Measurement of Credit Losses on Financial Instruments,” which was updated by subsequent amendments. This ASU replaces the current incurred loss model for measurement of credit losses on financial assets (including trade receivables) with a forward-looking expected loss model based on historical experience, current conditions, and reasonable and supportable forecasts. The guidance will bebecame effective for us as of January 1, 2020. We are currently evaluating2020 and resulted in the impact this guidance will haverecognition of $0.6 million (net of deferred taxes of $0.2 million) of allowances for expected credit losses related to our accounts receivable through a cumulative effect offset to retained earnings. The new credit loss standard is expected to accelerate recognition of credit losses on our consolidated financial statements.accounts receivable. See Note 17 for additional information regarding allowance for credit losses on our accounts receivable.
New accounting standards issued but not yet effective
We do not expect any other recentnew accounting standards to have a material impact on our financial position, results of operations or cash flows.flows when they become effective.
Note 2 — Company Overview
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 provide services and methodologies that we believe are critical to maximizing production economics. Our services cover the lifecycle of an offshore oil or gas field. We provide services primarily in deepwater in the Gulf of Mexico, Brazil, North Sea, Asia Pacific and West Africa regions. Our “lifelife of field”field services are segregated into 3 reportable business segments: Well Intervention, Robotics and Production Facilities (Note 12)13).
Our Well Intervention segment includes our vessels and/or equipment used to perform well intervention services primarily in the Gulf of Mexico, Brazil, the North Sea and West Africa. Our well intervention vessels include the Q4000, the Q5000, the Q7000, the Seawell, the Well Enhancer, and 2 chartered monohull vessels, the Siem Helix 1 and the Siem Helix 2. We also have a semi-submersible well intervention vessel under completion, the Q7000. Our well intervention equipment includes intervention riser systems (“IRSs”) and subsea intervention lubricators (“SILs”), some of which we provide on a stand-alone basis.
Our Robotics segment includes remotely operated vehicles (“ROVs”), trenchers and a ROVDrill, which are designed to complement offshore construction and well intervention services and 3offshore construction to both the oil and gas and the renewable energy markets. Our Robotics segment also includes 2 robotics support vessels under long-term charter: the Grand Canyon,charter, the Grand Canyon II and the Grand Canyon III. We also utilize, as well as spot vessels as needed, including the Ross Candies, which is under a flexible charter agreement.
Our Production Facilities segment includes the Helix Producer I (the “HP I”), a ship-shaped dynamically positioned floating production vessel, the Helix Fast Response System (the “HFRS”), our ownership interest in Independence Hub, LLC (“Independence Hub”) (Note 4), and several wellsour ownership of oil and related infrastructure associated with the Droshky Prospect that wegas properties acquired from Marathon Oil Corporation (“Marathon Oil”) onin January 18, 2019. All of our current production facilities activities are located in the Gulf of Mexico.
On May 29, 2019, we acquired a 70% controlling interest in Subsea Technologies Group Limited (“STL”), a subsea engineering firm based in Aberdeen, Scotland, for $5.1 million, including $4.1 million in cash and $1.0 million that we loaned to STL in December 2018. The acquisition is expected to strengthen our supply of subsea intervention systems.million. The holders of the remaining 30% noncontrolling interest have the right to put their shares to us in June 2024. These redeemable noncontrolling interests have beenwere recognized as temporary equity at their estimated fair value of $3.4 million at the acquisition date. We recognized $2.4 million of identifiable intangible assets and $6.9 million ofIn March 2020, we recorded an impairment loss to write off the goodwill which are reflected in “Other assets” inassociated with the accompanying condensed consolidated balance sheetSTL acquisition (Note 3)6). Goodwill is related to the synergies expected from the acquisition. The ultimate fair values of acquired assets, liabilities and noncontrolling interests are provisional and pending final assessment of the valuations. STL is included in our Well Intervention segment (Note 12)13) and its revenue and earnings are immaterial to our consolidated results.
Note 3 — Details of Certain Accounts
Other current assets consist of the following (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| | | | | | |
Contract assets (Note 9) | $ | 580 |
| | $ | 5,829 |
| |
Contract assets (Note 10) | | $ | 5,882 |
| | $ | 740 |
|
Prepaids | 14,876 |
| | 10,306 |
| 13,039 |
| | 12,635 |
|
Deferred costs (Note 9) | 26,424 |
| | 27,368 |
| |
Other receivable (Note 13) | 13,000 |
| | — |
| |
Deferred costs (Note 10) | | 28,481 |
| | 28,340 |
|
Income tax receivable | | 16,982 |
| | 1,261 |
|
Other | 6,871 |
| | 8,091 |
| 7,371 |
| | 7,474 |
|
Total other current assets | $ | 61,751 |
| | $ | 51,594 |
| $ | 71,755 |
| | $ | 50,450 |
|
Other assets, net consist of the following (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| | | | | | |
Prepaids | $ | 861 |
| | $ | 5,896 |
| $ | 694 |
| | $ | 777 |
|
Deferred recertification and dry dock costs, net | 16,678 |
| | 8,525 |
| 30,545 |
| | 16,065 |
|
Deferred costs (Note 9) | 20,695 |
| | 38,574 |
| |
Deferred costs (Note 10) | | 8,594 |
| | 14,531 |
|
Charter deposit (1) | 12,544 |
| | 12,544 |
| 12,544 |
| | 12,544 |
|
Other receivable (Note 13) | 26,702 |
| | — |
| |
Goodwill (Note 2) | 6,637 |
| | — |
| |
Intangible assets with finite lives, net (Note 2) | 3,703 |
| | 1,402 |
| |
Other receivable (2) | | 27,914 |
| | 27,264 |
|
Goodwill (Note 6) | | — |
| | 7,157 |
|
Intangible assets with finite lives, net | | 3,680 |
| | 3,847 |
|
Other | 2,503 |
| | 3,116 |
| 2,103 |
| | 2,323 |
|
Total other assets, net | $ | 90,323 |
| | $ | 70,057 |
| $ | 86,074 |
| | $ | 84,508 |
|
| |
(1) | This amount is deposited with the owner of the Siem Helix 2 to offset certain payment obligations associated with the vessel at the end of the charter term. |
| |
(2) | Agreed-upon amounts to be paid by Marathon Oil as the required plug and abandonment (“P&A”) work on the remaining Droshky wells is completed (Notes 7 and 14). |
Accrued liabilities consist of the following (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| | | | | | |
Accrued payroll and related benefits | $ | 25,853 |
| | $ | 43,079 |
| $ | 17,469 |
| | $ | 31,417 |
|
Investee losses in excess of investment (Note 4) | 7,638 |
| | 5,125 |
| 2,673 |
| | 4,069 |
|
Deferred revenue (Note 9) | 10,814 |
| | 10,103 |
| |
Asset retirement obligations (Note 13) | 11,556 |
| | — |
| |
Derivative liability (Note 17) | 2,723 |
| | 9,311 |
| |
Deferred revenue (Note 10) | | 11,376 |
| | 11,568 |
|
Derivative liability (Note 19) | | 26 |
| | 1,002 |
|
Other | 13,398 |
| | 17,976 |
| 13,683 |
| | 14,333 |
|
Total accrued liabilities | $ | 71,982 |
| | $ | 85,594 |
| $ | 45,227 |
| | $ | 62,389 |
|
Other non-current liabilities consist of the following (in thousands):
|
| | | | | | | |
| September 30, 2019 | | December 31, 2018 |
| | | |
Investee losses in excess of investment (Note 4) | $ | — |
| | $ | 6,035 |
|
Deferred gain on sale of property (1) | — |
| | 5,052 |
|
Deferred revenue (Note 9) | 9,196 |
| | 15,767 |
|
Asset retirement obligations (Note 13) | 27,564 |
| | — |
|
Derivative liability (Note 17) | — |
| | 884 |
|
Other | 2,248 |
| | 11,800 |
|
Total other non-current liabilities | $ | 39,008 |
| | $ | 39,538 |
|
|
| | | | | | | |
| March 31, 2020 | | December 31, 2019 |
| | | |
Deferred revenue (Note 10) | $ | 5,860 |
| | $ | 8,286 |
|
Asset retirement obligations (Note 14) | 28,934 |
| | 28,258 |
|
Other | 1,492 |
| | 2,100 |
|
Total other non-current liabilities | $ | 36,286 |
| | $ | 38,644 |
|
| |
(1) | Relates to the sale and lease-back in January 2016 of our office and warehouse property located in Aberdeen, Scotland. The deferred gain had been amortized over a 15-year minimum lease term prior to our adoption of ASC 842 on January 1, 2019. See Note 1 for the effect of ASC 842 on this deferred gain. |
Note 4 — Equity Method Investments
We have a 20% ownership interest in Independence Hub that we account for using the equity method of accounting. Independence Hub owns the “Independence Hub” platform, located in Mississippi Canyon Block 920which is in the Gulfprocess of Mexico in a water depth of 8,000 feet. We are committed to providing our pro-rata portion of financial support for Independence Hub to pay its obligations as they become due. The platform decommissioning process is currently underwaybeing decommissioned and is expected to be substantially completed within the next 12 months. We hadrecognized a liability of $7.6$2.7 million at September 30, 2019March 31, 2020 and $11.2$4.1 million at December 31, 20182019 for our share of Independence Hub’s estimated obligations, net of remaining working capital. This liability is reflected in “Accrued liabilities” and “Other non-current liabilities” in the accompanying condensed consolidated balance sheets.
Note 5 — Leases
We charter vessels and lease facilities and equipment under non-cancelable contracts that expire on various dates through 2031. We also sublease some of our facilities under non-cancelable sublease agreements.
Leases with a term greater than one year are recognized on our balance sheet as ROU assets and lease liabilities. We have elected to not recognize on our balance sheet leases with an initial term of one year or less. Lease liabilities and their corresponding ROU assets are recorded at the commencement date based on the present value of lease payments over the expected lease term. We use our incremental borrowing rate, which would be the rate incurred to borrow on a collateralized basis over a similar term in a similar economic environment, to calculate the present value of lease payments. ROU assets are adjusted for any initial direct costs paid or incentives received.
We separate our long-term vessel charters between their lease components and non-lease services. We estimate the lease component using the residual estimate approach by estimating the non-lease services, which are primarily crew, repair and maintenance, and regulatory certification costs. For all other leases, we have not separated the lease components and non-lease services. The lease term may include options to extend or terminate the lease when it is reasonably certain that we will exercise the option.
We recognize operating lease cost on a straight-line basis over the lease term for both (i) leases that are recognized on the balance sheet and (ii) short-term leases. We recognize lease cost related to variable lease payments that are not recognized on the balance sheet in the period in which the obligation is incurred. The following table details the components of our lease cost (in thousands):
| | | Three Months Ended | | Nine Months Ended | Three Months Ended March 31, |
| September 30, 2019 | | September 30, 2019 | 2020 | | 2019 |
| | | | | | |
Operating lease cost | $ | 18,002 |
| | $ | 54,191 |
| $ | 16,323 |
| | $ | 18,133 |
|
Variable lease cost | 3,630 |
| | 9,927 |
| 3,212 |
| | 3,075 |
|
Short-term lease cost | 5,587 |
| | 14,549 |
| 7,174 |
| | 4,158 |
|
Sublease income | (351 | ) | | (1,077 | ) | (279 | ) | | (353 | ) |
Net lease cost | $ | 26,868 |
| | $ | 77,590 |
| $ | 26,430 |
| | $ | 25,013 |
|
Maturities of our operating lease liabilities as of March 31, 2020 are as follows (in thousands):
|
| | | | | | | | | | | |
| Vessels | | Facilities and Equipment | | Total |
| | | | | |
Remainder of 2020 | $ | 44,316 |
| | $ | 4,619 |
| | $ | 48,935 |
|
2021 | 54,184 |
| | 5,630 |
| | 59,814 |
|
2022 | 52,106 |
| | 5,109 |
| | 57,215 |
|
2023 | 34,580 |
| | 4,565 |
| | 39,145 |
|
2024 | 2,470 |
| | 4,299 |
| | 6,769 |
|
Thereafter | — |
| | 5,954 |
| | 5,954 |
|
Total lease payments | $ | 187,656 |
| | $ | 30,176 |
| | $ | 217,832 |
|
Less: imputed interest | (21,611 | ) | | (5,747 | ) | | (27,358 | ) |
Total operating lease liabilities | $ | 166,045 |
| | $ | 24,429 |
| | $ | 190,474 |
|
| | | | | |
Current operating lease liabilities | $ | 48,296 |
| | $ | 4,767 |
| | $ | 53,063 |
|
Non-current operating lease liabilities | 117,749 |
| | 19,662 |
| | 137,411 |
|
Total operating lease liabilities | $ | 166,045 |
| | $ | 24,429 |
| | $ | 190,474 |
|
Maturities of our operating lease liabilities as of September 30,December 31, 2019 are as follows (in thousands):
| | | Vessels | | Facilities and Equipment | | Total | Vessels | | Facilities and Equipment | | Total |
| | | | | | | | | | |
Remainder of 2019 | $ | 15,416 |
| | $ | 1,717 |
| | $ | 17,133 |
| |
2020 | 59,942 |
| | 6,391 |
| | 66,333 |
| $ | 60,210 |
| | $ | 6,610 |
| | $ | 66,820 |
|
2021 | 54,481 |
| | 5,694 |
| | 60,175 |
| 54,564 |
| | 5,888 |
| | 60,452 |
|
2022 | 52,105 |
| | 5,103 |
| | 57,208 |
| 52,106 |
| | 5,257 |
| | 57,363 |
|
2023 | 34,580 |
| | 4,522 |
| | 39,102 |
| 34,580 |
| | 4,622 |
| | 39,202 |
|
2024 | | 2,470 |
| | 4,349 |
| | 6,819 |
|
Thereafter | 2,470 |
| | 10,163 |
| | 12,633 |
| — |
| | 6,251 |
| | 6,251 |
|
Total lease payments | $ | 218,994 |
| | $ | 33,590 |
| | $ | 252,584 |
| $ | 203,930 |
| | $ | 32,977 |
| | $ | 236,907 |
|
Less: imputed interest | (28,272 | ) | | (6,711 | ) | | (34,983 | ) | (24,846 | ) | | (6,449 | ) | | (31,295 | ) |
Total operating lease liabilities | $ | 190,722 |
| | $ | 26,879 |
| | $ | 217,601 |
| $ | 179,084 |
| | $ | 26,528 |
| | $ | 205,612 |
|
| | | | | | | | | | |
Current operating lease liabilities | $ | 47,914 |
| | $ | 4,926 |
| | $ | 52,840 |
| $ | 48,716 |
| | $ | 5,069 |
| | $ | 53,785 |
|
Non-current operating lease liabilities | 142,808 |
| | 21,953 |
| | 164,761 |
| 130,368 |
| | 21,459 |
| | 151,827 |
|
Total operating lease liabilities | $ | 190,722 |
| | $ | 26,879 |
| | $ | 217,601 |
| $ | 179,084 |
| | $ | 26,528 |
| | $ | 205,612 |
|
The following table presents the weighted average remaining lease term and discount rate:
|
| | |
| September 30, 2019 |
| |
Weighted average remaining lease term | 4.2 years |
|
Weighted average discount rate | 7.54 | % |
|
| | | | | |
| March 31, 2020 | | December 31, 2019 |
| | | |
Weighted average remaining lease term | 3.7 years |
| | 4.0 years |
|
Weighted average discount rate | 7.53 | % | | 7.54 | % |
The following table presents other information related to our operating leases (in thousands):
|
| | | |
| Nine Months Ended |
| September 30, 2019 |
| |
Cash paid for operating lease liabilities | $ | 54,538 |
|
ROU assets obtained in exchange for new operating lease obligations | 921 |
|
As previously disclosed in our 2018 Form 10-K and under the previous lease accounting standard, future minimum lease payments for our operating leases as of December 31, 2018 were as follows (in thousands):
|
| | | | | | | | | | | |
| Vessels | | Facilities and Equipment | | Total |
| | | | | |
2019 | $ | 116,620 |
| | $ | 5,881 |
| | $ | 122,501 |
|
2020 | 96,800 |
| | 5,340 |
| | 102,140 |
|
2021 | 89,216 |
| | 5,185 |
| | 94,401 |
|
2022 | 90,371 |
| | 5,064 |
| | 95,435 |
|
2023 | 51,266 |
| | 4,533 |
| | 55,799 |
|
Thereafter | — |
| | 10,448 |
| | 10,448 |
|
Total lease payments | $ | 444,273 |
| | $ | 36,451 |
| | $ | 480,724 |
|
|
| | | | | | | |
| Three Months Ended March 31, |
| 2020 | | 2019 |
| | | |
Cash paid for operating lease liabilities | $ | 16,472 |
| | $ | 17,148 |
|
ROU assets obtained in exchange for new operating lease obligations | — |
| | 89 |
|
Note 6 — Goodwill
The changes in the carrying amount of goodwill are as follows (in thousands):
|
| | | |
| Well Intervention |
| |
Balance at December 31, 2019 | $ | 7,157 |
|
Impairment loss (1) | (6,689 | ) |
Other adjustments (2) | (468 | ) |
Balance at March 31, 2020 | $ | — |
|
| |
(1) | As a result of the decline in oil prices as well as energy and energy services valuations during the three-month period ended March 31, 2020 due to the ongoing COVID-19 pandemic and the OPEC+ price war, we identified that it was more likely than not that the fair value of goodwill associated with our STL acquisition (Note2) was less than its carrying amount. Based on the result of our goodwill impairment test as of March 31, 2020, we recorded a charge to write off the carrying amount of the goodwill. The fair value of the reporting unit used to determine the impairment was estimated using a discounted cash flow approach. |
| |
(2) | Relates to foreign currency adjustments. |
Note 67 — Long-Term Debt
Scheduled maturities of our long-term debt outstanding as of September 30, 2019March 31, 2020 are as follows (in thousands):
| | | Term Loan (1) | | 2022 Notes | | 2023 Notes | | MARAD Debt | | Nordea Q5000 Loan | | Total | Term Loan (1) | | 2022 Notes | | 2023 Notes | | MARAD Debt | | Nordea Q5000 Loan | | Total |
| | | | | | | | | | | | | | | | | | | | | | |
Less than one year | $ | 3,500 |
| | $ | — |
| | $ | — |
| | $ | 7,200 |
| | $ | 98,214 |
| | $ | 108,914 |
| $ | 3,500 |
| | $ | — |
| | $ | — |
| | $ | 7,378 |
| | $ | 80,357 |
| | $ | 91,235 |
|
One to two years | 3,500 |
| | — |
| | — |
| | 7,560 |
| | — |
| | 11,060 |
| 28,875 |
| | — |
| | — |
| | 7,746 |
| | — |
| | 36,621 |
|
Two to three years | 27,125 |
| | 125,000 |
| | — |
| | 7,937 |
| | — |
| | 160,062 |
| — |
| | 125,000 |
| | — |
| | 8,133 |
| | — |
| | 133,133 |
|
Three to four years | — |
| | — |
| | 125,000 |
| | 8,333 |
| | — |
| | 133,333 |
| — |
| | — |
| | 125,000 |
| | 8,538 |
| | — |
| | 133,538 |
|
Four to five years | — |
| | — |
| | — |
| | 8,749 |
| | — |
| | 8,749 |
| — |
| | — |
| | — |
| | 8,965 |
| | — |
| | 8,965 |
|
Over five years | — |
| | — |
| | — |
| | 23,831 |
| | — |
| | 23,831 |
| — |
| | — |
| | — |
| | 19,294 |
| | — |
| | 19,294 |
|
Gross debt | 34,125 |
| | 125,000 |
| | 125,000 |
| | 63,610 |
| | 98,214 |
| | 445,949 |
| 32,375 |
| | 125,000 |
| | 125,000 |
| | 60,054 |
| | 80,357 |
| | 422,786 |
|
Unamortized debt discounts (2) | — |
| | (8,784 | ) | | (15,376 | ) | | — |
| | — |
| | (24,160 | ) | — |
| | (7,207 | ) | | (13,700 | ) | | — |
| | — |
| | (20,907 | ) |
Unamortized debt issuance costs (3) | (438 | ) | | (1,368 | ) | | (2,478 | ) | | (3,659 | ) | | (446 | ) | | (8,389 | ) | (334 | ) | | (1,103 | ) | | (2,208 | ) | | (3,415 | ) | | (398 | ) | | (7,458 | ) |
Total debt | 33,687 |
| | 114,848 |
| | 107,146 |
| | 59,951 |
| | 97,768 |
| | 413,400 |
| 32,041 |
| | 116,690 |
| | 109,092 |
| | 56,639 |
| | 79,959 |
| | 394,421 |
|
Less: current maturities | (3,500 | ) | | — |
| | — |
| | (7,200 | ) | | (97,768 | ) | | (108,468 | ) | (3,500 | ) | | — |
| | — |
| | (7,378 | ) | | (79,959 | ) | | (90,837 | ) |
Long-term debt | $ | 30,187 |
| | $ | 114,848 |
| | $ | 107,146 |
| | $ | 52,751 |
| | $ | — |
| | $ | 304,932 |
| $ | 28,541 |
| | $ | 116,690 |
| | $ | 109,092 |
| | $ | 49,261 |
| | $ | — |
| | $ | 303,584 |
|
| |
(1) | Term Loan pursuant to the Credit Agreement (as defined below) matures in December 2021. |
| |
(2) | Our Convertible Senior Notes due 2022 and 2023 will increase to their face amounts through accretion of their debt discounts to interest expense through May 2022 and September 2023, respectively. |
| |
(3) | Debt issuance costs are amortized to interest expense over the term of the applicable debt agreement. |
Below is a summary of certain components of our indebtedness:
Credit Agreement
On June 30, 2017, we entered into an Amended and Restated Credit Agreement (and the amendments made thereafter, collectively the “Credit Agreement”) with a group of lenders led by Bank of America, N.A. (“Bank of America”). On June 28, 2019, we amended our existing term loan (the “Term Loan”) and revolving credit facility (the “Revolving Credit Facility”) under the Credit Agreement. The Credit Agreement is comprised of a $35 million Term Loan and a Revolving Credit Facility of $175 million.million and matures on December 31, 2021. The Revolving Credit Facility permits us to obtain letters of credit up to a sublimit of $25 million. Pursuant to the Credit Agreement, subject to existing lender participation and/or the participation of new lenders, and subject to standard conditions precedent, we may request aggregate commitments of up to $100 million with respect to an increase in the Revolving Credit Facility. As of September 30, 2019,March 31, 2020, we had no borrowings under the Revolving Credit Facility, and our available borrowing capacity under that facility, based on the leverage ratios, totaled $172.6 million, net of $2.4 million of letters of credit issued under that facility.
Borrowings under the Credit Agreement bear interest, at our election, at either Bank of America’s base rate, the LIBOR or a comparable successor rate, or a combination thereof. The Term Loan bearing interest at the base rate will bear interest at a per annum rate equal to Bank of America’s base rate plus a margin of 2.25%. The Term Loan bearing interest at a LIBOR rate will bear interest per annum at the LIBOR or a comparable successor rate selected by us plus a margin of 3.25%. The interest rate on the Term Loan was 5.29%4.24% as of September 30, 2019.March 31, 2020. Borrowings under the Revolving Credit Facility bearing interest at the base rate will bear interest at a per annum rate equal to Bank of America’s base rate plus a margin ranging from 1.50% to 2.50%. Borrowings under the Revolving Credit Facility bearing interest at a LIBOR rate will bear interest per annum at the LIBOR or a comparable successor rate selected by us plus a margin ranging from 2.50% to 3.50%. A letter of credit fee is payable by us equal to the applicable margin for LIBOR rate loans multiplied by the daily amount available to be drawn under the applicable letter of credit. Margins on borrowings under the Revolving Credit Facility will vary in relation to the Consolidated Total Leverage Ratio (as defined below) as provided for in the Credit Agreement. We also pay a fixed commitment fee of 0.50% per annum on the unused portion of the Revolving Credit Facility.
The Term Loan principal is required to be repaid in quarterly installments of 2.5% of the aggregate principal amount of the Term Loan, with a balloon payment at maturity. Installment amounts are subject to adjustment for any prepayments on the Term Loan. We may prepay indebtedness outstanding under the Term Loan without premium or penalty, but may not reborrow any amounts prepaid. We may prepay indebtedness outstanding under the Revolving Credit Facility without premium or penalty, and may reborrow any amounts prepaid up to the amount ofavailable under the Revolving Credit Facility. Borrowings
Our obligations under the Credit Agreement, mature on December 31, 2021.and those of our subsidiary guarantors under their guarantee, are secured by (i) most of the assets of the parent company, (ii) the shares of our domestic subsidiaries (other than Cal Dive I - Title XI, Inc.) and of Helix Robotics Solutions Limited and (iii) most of the assets of our domestic subsidiaries (other than Cal Dive I - Title XI, Inc.) and of Helix Robotics Solutions Limited. In addition, these obligations are secured by pledges of up to 66% of the shares of certain foreign subsidiaries (restricted subsidiaries).
The Credit Agreement and the other documents entered into in connection with the Credit Agreement include terms and conditions, including covenants, which we consider customary for this type of transaction. The covenants include certain restrictions on our and certain of our subsidiaries’ ability to grant liens, incur indebtedness, make investments, merge or consolidate, sell or transfer assets, pay dividends and make capital expenditures. In addition, the Credit Agreement obligates us to meet minimum ratio requirements of EBITDA to interest charges (Consolidated Interest Coverage Ratio), funded debt to EBITDA (Consolidated Total Leverage Ratio) and secured funded debt to EBITDA (Consolidated Secured Leverage Ratio).
We may designate one or more of our new foreign subsidiaries as subsidiaries not generally subject to the covenants in the Credit Agreement (the “Unrestricted Subsidiaries”). The Unrestricted Subsidiaries are not pledged as collateral under the Credit Agreement, and the debt and EBITDA of the Unrestricted Subsidiaries with the exception of Helix Q5000 Holdings, S.à r.l. (“Q5000 Holdings”), a wholly owned Luxembourg subsidiary incorporated in Luxembourg,of Helix Vessel Finance S.à r.l., are not included in the calculations of our financial covenants. Our obligations undercovenants except to the Credit Agreement, and thoseextent of ourany cash actually distributed by such subsidiary guarantors under their guarantee, are secured by (i) most of the assets of the parent company, (ii) the shares of our domestic subsidiaries (other than Cal Dive I - Title XI, Inc.) and of Helix Robotics Solutions Limited (formerly known as Canyon Offshore Limited) and (iii) most of the assets of our domestic subsidiaries (other than Cal Dive I - Title XI, Inc.) and of Helix Robotics Solutions Limited. In addition, these obligations are secured by pledges of up to 66% of the shares of certain foreign subsidiaries.Helix.
In March 2018, we prepaid $61 million
In January 2019, contemporaneously with our purchaseacquisition from Marathon Oil of several wells and related infrastructure associated with the Droshky Prospect located in offshore Gulf of Mexico Green Canyon Block 244, we amended the Credit Agreement to permit the issuance of certain security to third parties for required plug and abandonment (“P&A”)&A obligations and to make certain capital expenditures in connection with acquired assets (Notes 2 and 13)14).
Convertible Senior Notes Due 2022 (“2022 Notes”)
On November 1, 2016, we completed a public offering and sale of the 2022 Notes in the aggregate principal amount of $125 million. The 2022 Notes bear interest at a rate of 4.25% per annum and are payable semi-annually in arrears on November 1 and May 1 of each year, beginning on May 1, 2017. The 2022 Notes mature on May 1, 2022 unless earlier converted, redeemed or repurchased. During certain periods and subject to certain conditions, the 2022 Notes are convertible by the holders into shares of our common stock at an initial conversion rate of 71.9748 shares of our common stock per $1,000 principal amount (which represents an initial conversion price of approximately $13.89 per share of common stock), subject to adjustment in certain circumstances. We have the right and the intention to settle the principal amount of any such future conversions in cash.
Prior to November 1, 2019, the 2022 Notes arewere not redeemable. On or afterBeginning November 1, 2019, if certain conditions are met, we may redeem all or any portion of the 2022 Notes at a redemption price payable in cash equal to 100% of the principal amount to be redeemed plus accrued and unpaid interest and a “make-whole premium” (as defined in the indenture governing the 2022 Notes). Holders of the 2022 Notes may require us to repurchase the notes following a “fundamental change” (as defined in the indenture governing the 2022 Notes).
The indenture governing the 2022 Notes contains customary terms and covenants, including that upon certain events of default occurring and continuing, either the trustee under the indenture or the holders of not less than 25% in aggregate principal amount then outstanding under the 2022 Notes may declare the entire principal amount of all the notes, and the interest accrued on such notes, if any, to be immediately due and payable. In the case of certain events of bankruptcy, insolvency or reorganization relating to us or a significant subsidiary, the principal amount of the 2022 Notes together with any accrued and unpaid interest thereon will become immediately due and payable.
The 2022 Notes arewere initially accounted for by separating the net proceeds between long-term debt and shareholders’ equity. In connection with the issuance of the 2022 Notes, we recorded a debt discount of $16.9 million ($11.0 million net of tax) as a result of separating the equity component. The effective interest rate for the 2022 Notes is 7.3% after considering the effect of the accretion of the related debt discount that representedover the equity componentterm of the 2022 Notes at their inception. For the three- and nine-month periods ended September 30, 2019, interestNotes. Interest expense (including amortization of the debt discount) related to the 2022 Notes totaled $2.1 million and $6.2 million, respectively. Forfor each of the three- and nine-monththree-month periods ended September 30, 2018, interest expense (including amortization of the debt discount) related to the 2022 Notes totaled $2.0 millionMarch 31, 2020 and $6.1 million, respectively.2019. The remaining unamortized debt discount of the 2022 Notes was $8.8$7.2 million at September 30, 2019March 31, 2020 and $11.0$8.0 million at December 31, 2018.2019.
Convertible Senior Notes Due 2023 (“2023 Notes”)
On March 20, 2018, we completed a public offering and sale of the 2023 Notes in the aggregate principal amount of $125 million. The net proceeds from the issuance of the 2023 Notes were approximately $121.0 million after deducting the underwriters’ discounts and commissions and estimated offering expenses. We used the net proceeds from the issuance of the 2023 Notes to fund the required repurchase by us of $59.3 million in principal of Convertible Senior Notes due 2032 (the “2032 Notes”) described below and to prepay $61.0 million of the then-existing term loan.
The 2023 Notes bear interest at a rate of 4.125% per annum and are payable semi-annually in arrears on March 15 and September 15 of each year, beginning on September 15, 2018. The 2023 Notes mature on September 15, 2023 unless earlier converted, redeemed or repurchased. During certain periods and subject to certain conditions, the 2023 Notes are convertible by the holders into shares of our common stock at an initial conversion rate of 105.6133 shares of our common stock per $1,000 principal amount (which represents an initial conversion price of approximately $9.47 per share of common stock), subject to adjustment in certain circumstances. We have the right and the intention to settle the principal amount of any such future conversions in cash.
Prior to March 15, 2021, the 2023 Notes are not redeemable. On or after March 15, 2021, if certain conditions are met, we may redeem all or any portion of the 2023 Notes at a redemption price payable in cash equal to 100% of the principal amount to be redeemed plus accrued and unpaid interest and a “make-whole premium” (as defined in the indenture governing the 2023 Notes). Holders of the 2023 Notes may require us to repurchase the notes following a “fundamental change” (as defined in the indenture governing the 2023 Notes).
The indenture governing the 2023 Notes contains customary terms and covenants, including that upon certain events of default occurring and continuing, either the trustee under the indenture or the holders of not less than 25% in aggregate principal amount then outstanding under the 2023 Notes may declare the entire principal amount of all the notes, and the interest accrued on such notes, if any, to be immediately due and payable. In the case of certain events of bankruptcy, insolvency or reorganization relating to us or a significant subsidiary, the principal amount of the 2023 Notes together with any accrued and unpaid interest thereon will become immediately due and payable.
The 2023 Notes arewere initially accounted for by separating the net proceeds between long-term debt and shareholders’ equity. In connection with the issuance of the 2023 Notes, we recorded a debt discount of $20.1 million ($15.9 million net of tax) as a result of separating the equity component. The effective interest rate for the 2023 Notes is 7.8% after considering the effect of the accretion of the related debt discount that representedover the equity componentterm of the 2023 Notes at their inception. For the three- and nine-month periods ended September 30, 2019, interestNotes. Interest expense (including amortization of the debt discount) related to the 2023 Notes totaled $2.1 million and $6.3 million, respectively. Forfor each of the three- and nine-monththree-month periods ended September 30, 2018, interest expense (including amortization of the debt discount) related to the 2023 Notes totaled $2.1 millionMarch 31, 2020 and $4.3 million, respectively.2019. The remaining unamortized debt discount of the 2023 Notes was $15.4$13.7 million at September 30, 2019March 31, 2020 and $17.8$14.5 million at December 31, 2018.2019.
MARAD Debt
This U.S. government-guaranteed financing (the “MARAD Debt”), pursuant to Title XI of the Merchant Marine Act of 1936 administered by the Maritime Administration, was used to finance the construction of the Q4000. The MARAD Debt is collateralized by the Q4000 and is guaranteed 50% by us. The MARAD Debt is payable in equal semi-annual installments, matures in February 2027 and bears interest at a rate of 4.93%.
Nordea Credit Agreement
In September 2014, Q5000 Holdings entered into a credit agreement (the “Nordea Credit Agreement”) with a syndicated bank lending group for a term loan (the “Nordea Q5000 Loan”) in an amount of up to $250 million. The Nordea Q5000 Loan was funded in the amount of $250 million in April 2015 at the time the Q5000 was delivered to us. The parent company of Q5000 Holdings, Helix Vessel Finance S.à r.l., also a direct wholly owned Luxembourg subsidiary of Helix, guaranteed the Nordea Q5000 Loan. The loan is secured by the Q5000 and its charter earnings as well as by a pledge of the shares of Q5000 Holdings. This indebtedness is non-recourse to Helix.
TheWe amended the Nordea Q5000 Loan bearson March 11, 2020. Prior to the amendment, the Nordea Q5000 Loan incurred interest at a LIBOR rate plus a margin of 2.5%. The Nordea Q5000 Loan matures on April 30, 2020 and iswas repayable in scheduled quarterly principal installments of $8.9 million with a balloon payment of $80.4 million at maturity.on April 30, 2020. The amendment increases the margin to 2.75%, maintains the existing quarterly amortization requirements, and extends the final maturity to January 31, 2021 with a balloon payment on that date of $53.6 million. The remaining principal balance and unamortized debt issuance costs related to the Nordea Q5000 Loan are classified as current. Q5000 Holdingscurrent in the accompanying condensed consolidated balance sheets. We may elect to prepay indebtedness outstanding under the Nordea Q5000 Loan without premium or penalty, but may not reborrow any amounts prepaid. Quarterly principal installments are subject to adjustment for any prepayments on this debt. In June 2015, we entered into interest rate swap contracts to fix the one-month LIBOR rate on a portion of our borrowings under the Nordea Q5000 Loan (Note 17). The total notional amount of the swaps (initially $187.5 million) decreases in proportion to the reduction in the principal amount outstanding under the Nordea Q5000 Loan. The fixed LIBOR rates are approximately 150 basis points.
The Nordea Credit Agreement and related loan documents include terms and conditions, including covenants and prepayment requirements, that we consider 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 certain minimum financial requirements, including liquidity, consolidated debt service coverage and collateral maintenance.
Convertible Senior Notes Due 2032
In March 2012, we issued $200 million of 3.25% Convertible Senior Notes, which were originally scheduled to mature on March 15, 2032. In March 2018, we made a tender offer for the repurchase of the 2032 Notes outstanding on the first repurchase date as required by the indenture governing the 2032 Notes, and as a result we repurchased $59.3 million in aggregate principal amount of the 2032 Notes on March 20, 2018. The total repurchase price was $59.5 million, including $0.2 million in fees. We recognized a $0.2 million loss in connection with the repurchase of the 2032 Notes. The loss is presented as “Loss on extinguishment of long-term debt” in the accompanying condensed consolidated statement of operations. On May 4, 2018, we redeemed the remaining $0.8 million in aggregate principal amount of the 2032 Notes.
Other
In accordance with the Credit Agreement, the 2022 Notes, the 2023 Notes, the MARAD Debt agreements and the Nordea Credit Agreement, we are required to comply with certain covenants, including with respect to the Credit Agreement, certain financial ratios such as a consolidated interest coverage ratio, a consolidated total leverage ratio and a consolidated secured leverage ratio, as well as the maintenance of minimum cash balance, net worth, working capital and debt-to-equity requirements. As of September 30, 2019,March 31, 2020, we were in compliance with these covenants.
The following table details the components of our net interest expense (in thousands):
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 | 2020 | | 2019 |
| | | | | | | | | | |
Interest expense | $ | 7,694 |
| | $ | 8,171 |
| | $ | 23,635 |
| | $ | 24,511 |
| $ | 7,394 |
| | $ | 7,896 |
|
Interest income | (652 | ) | | (994 | ) | | (2,085 | ) | | (2,263 | ) | (466 | ) | | (758 | ) |
Capitalized interest | (5,141 | ) | | (3,928 | ) | | (15,346 | ) | | (11,504 | ) | (1,182 | ) | | (5,040 | ) |
Net interest expense | $ | 1,901 |
| | $ | 3,249 |
| | $ | 6,204 |
| | $ | 10,744 |
| $ | 5,746 |
| | $ | 2,098 |
|
Note 78 — Income Taxes
We believe that our recorded deferred tax assets and liabilities are reasonable. However, tax laws and regulations are subject to interpretation, and the outcomes of tax disputes are inherently uncertain; therefore, our assessments can involve a series of complex judgments about future events and rely heavily on estimates and assumptions.
The CARES Act, which was signed into law on March 27, 2020, is an economic stimulus package designed to aid in offsetting the economic damage caused by the ongoing COVID-19 pandemic and includes various changes to U.S. income tax regulations. The CARES Act permits the carryback of certain net operating losses, which previously had been required to be carried forward, at the tax rates applicable in the relevant carryback year. As a result of these changes, we recognized an estimated $5.8 million net tax benefit in the three-month period ended March 31, 2020, consisting of a $15.9 million current tax benefit and a $10.1 million deferred tax expense. This $5.8 million net tax benefit resulted from our deferred tax assets related to our net operating losses in the U.S. being utilized at the previous higher income tax rate applicable to the carryback periods.
We adopted the discrete effective tax ratesrate method for recording income taxes for the three-three-month period ended March 31, 2020. The discrete method is applied when the application of the estimated annual effective tax rate is impractical because it is not possible to reliably estimate the annual effective tax rate. The discrete method treats the year-to-date period as if it were the annual period and nine-month periods ended September 30, 2019 were 10.1%determines the income tax expense or benefit on that basis. We believe that the use of the discrete method is more appropriate than the annual effective tax rate method because of the current high degree of uncertainty in estimating annual pretax earnings created by uncertainty in future market conditions caused by the ongoing COVID-19 pandemic as well as uncertainty in the oil and 11.9%, respectively. gas market. We will re-evaluate our use of this method each quarter until such time as a return to the annualized effective tax rate method is deemed appropriate.
The effective tax rates for the three- and nine-monththree-month periods ended September 30, 2018March 31, 2020 and 2019 were 3.0%60.2% benefit and 2.8%,19.7% expense, respectively. The increases werevariance in the effective tax rate was primarily attributable to improvements in profitability inour carrying back certain net operating losses to prior periods with higher income tax rates as well as the result of the consolidation of certain U.S. year over year.branch operations with the Helix U.S. consolidated tax group.
Income taxes are provided based on the U.S. statutory rate 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 U.S. statutory rate and our effective rate are as follows:
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 | 2020 | | 2019 |
| | | | | | | | | | |
U.S. statutory rate | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | 21.0 | % | | 21.0 | % |
Foreign provision | (10.1 | ) | | (18.5 | ) | | (9.7 | ) | | (19.1 | ) | (3.0 | ) | | (2.7 | ) |
CARES Act | | 16.6 |
| | — |
|
Subsidiary restructuring | | 23.8 |
| | — |
|
Other | (0.8 | ) | | 0.5 |
| | 0.6 |
| | 0.9 |
| 1.8 |
| | 1.4 |
|
Effective rate | 10.1 | % | | 3.0 | % | | 11.9 | % | | 2.8 | % | 60.2 | % | | 19.7 | % |
Note 89 — Shareholders’ Equity
The components of accumulated other comprehensive loss (“accumulated OCI”) are as follows (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| | | | | | |
Cumulative foreign currency translation adjustment | $ | (74,419 | ) | | $ | (69,855 | ) | $ | (98,042 | ) | | $ | (64,455 | ) |
Net unrealized loss on hedges, net of tax (1) | (781 | ) | | (4,109 | ) | (20 | ) | | (285 | ) |
Accumulated OCI | $ | (75,200 | ) | | $ | (73,964 | ) | $ | (98,062 | ) | | $ | (64,740 | ) |
| |
(1) | Relates to foreign currency hedges for the Grand Canyon II and Grand Canyon III charterscharter as well as interest rate swaphedge contracts for the Nordea Q5000 Loan (Note 17) and is net of deferred income taxes totaling $0.2 million at September 30, 2019 and $1.0 million at December 31, 2018.19). |
Note 910 — Revenue from Contracts with Customers
Disaggregation of Revenue
Our revenues are derived primarily from short-term and long-term service contracts with customers. Our service contracts generally contain either provisions for specific time, material and equipment charges that are billed in accordance with the terms of such contracts (dayrate contracts) or lump sum payment provisions (lump sum contracts). We record revenues net of taxes collected from customers and remitted to governmental authorities. The following table provides information about disaggregated revenue by contract duration (in thousands):
| | | | Well Intervention | | Robotics | | Production Facilities | | Intercompany Eliminations (1) | | Total Revenue | | Well Intervention | | Robotics | | Production Facilities | | Intercompany Eliminations (1) | | Total Revenue |
Three months ended September 30, 2019 | | | | | | | | | | | |
Short-term | $ | 53,018 |
| | $ | 26,809 |
| | $ | — |
| | $ | — |
| | $ | 79,827 |
| |
Long-term (2) | 117,188 |
| | 25,100 |
| | 13,777 |
| | (23,283 | ) | | 132,782 |
| |
Total | $ | 170,206 |
| | $ | 51,909 |
| | $ | 13,777 |
| | $ | (23,283 | ) | | $ | 212,609 |
| |
| | | | | | | | | | | |
Three months ended September 30, 2018 | | | | | | | | | | | |
Three months ended March 31, 2020 | | | | | | | | | | | |
Short-term | Short-term | $ | 39,548 |
| | $ | 29,877 |
| | $ | — |
| | $ | — |
| | $ | 69,425 |
| Short-term | $ | 82,324 |
| | $ | 22,441 |
| | $ | — |
| | $ | — |
| | $ | 104,765 |
|
Long-term (2) | Long-term (2) | 114,893 |
| | 24,463 |
| | 15,877 |
| | (12,083 | ) | | 143,150 |
| Long-term (2) | 58,328 |
| | 12,817 |
| | 15,541 |
| | (10,430 | ) | | 76,256 |
|
Total | Total | $ | 154,441 |
| | $ | 54,340 |
| | $ | 15,877 |
| | $ | (12,083 | ) | | $ | 212,575 |
| Total | $ | 140,652 |
| | $ | 35,258 |
| | $ | 15,541 |
| | $ | (10,430 | ) | | $ | 181,021 |
|
| | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | |
Nine months ended September 30, 2019 | | | | | | | | | | | |
Three months ended March 31, 2019 | | | | | | | | | | | |
Short-term | Short-term | $ | 145,611 |
| | $ | 80,440 |
| | $ | — |
| | $ | — |
| | $ | 226,051 |
| Short-term | $ | 29,805 |
| | $ | 24,930 |
| | $ | — |
| | $ | — |
| | $ | 54,735 |
|
Long-term (2) | Long-term (2) | 305,900 |
| | 55,956 |
| | 44,651 |
| | (51,398 | ) | | 355,109 |
| Long-term (2) | 92,426 |
| | 14,111 |
| | 15,253 |
| | (9,702 | ) | | 112,088 |
|
Total | Total | $ | 451,511 |
| | $ | 136,396 |
| | $ | 44,651 |
| | $ | (51,398 | ) | | $ | 581,160 |
| Total | $ | 122,231 |
| | $ | 39,041 |
| | $ | 15,253 |
| | $ | (9,702 | ) | | $ | 166,823 |
|
| | | | | | | | | | | |
Nine months ended September 30, 2018 | | | | | | | | | | | |
Short-term | $ | 143,510 |
| | $ | 74,050 |
| | $ | — |
| | $ | — |
| | $ | 217,560 |
| |
Long-term (2) | 302,259 |
| | 46,519 |
| | 48,541 |
| | (33,417 | ) | | 363,902 |
| |
Total | $ | 445,769 |
| | $ | 120,569 |
| | $ | 48,541 |
| | $ | (33,417 | ) | | $ | 581,462 |
| |
| |
(1) | Intercompany revenues among our business segments are under agreements that are considered long-term. |
| |
(2) | Contracts are classified as long-term if all or part of the contract is to be performed over a period extending beyond 12 months from the effective date of the contract. Long-term contracts may include multi-year agreements whereby the commitment for services in any one year may be short in duration. |
Contract Balances
Accounts receivable are recognized when our right to consideration becomes unconditional. Accounts receivable that have been billed to customers are recorded as trade accounts receivable while accounts receivable that have not been billed to customers are recorded as unbilled accounts receivable.
Contract assets are rights to consideration in exchange for services that we have provided to a customer when those rights are conditioned on our future performance. Contract assets generally consist of (i) demobilization fees recognized ratably over the contract term but invoiced upon completion of the demobilization activities and (ii) revenue recognized in excess of the amount billed to the customer for lump sum contracts when the cost-to-cost method of revenue recognition is utilized. Contract assets are reflected in “Other current assets” onin the accompanying condensed consolidated balance sheets (Note 3). Contract assets were $0.6$5.9 million at September 30, 2019March 31, 2020 and $5.8$0.7 million at December 31, 2018.2019. We incurredhad no impairment losses on our accounts receivable and contract assets for the three- and nine-monththree-month periods ended September 30, 2019March 31, 2020 and 2018.2019.
Contract liabilities are obligations to provide future services to a customer for which we have already received, or have the unconditional right to receive, the consideration for those services from the customer. Contract liabilities may consist of (i) advance payments received from customers, including upfront mobilization fees allocated to a single performance obligation and recognized ratably over the contract term and/or (ii) amounts billed to the customer in excess of revenue recognized for lump sum contracts when the cost-to-cost method of revenue recognition is utilized. Contract liabilities are reflected as “Deferred revenue,” a component of “Accrued liabilities” and “Other non-current liabilities” onin the accompanying condensed consolidated balance sheets (Note 3). Contract liabilities totaled $20.0$17.2 million at September 30, 2019March 31, 2020 and $25.9$19.9 million at December 31, 2018.2019. Revenue recognized for the three- and nine-monththree-month periods ended September 30,March 31, 2020 and 2019 included $4.0$3.4 million and $7.4 million, respectively, that were included in the contract liability balance at the beginning of each period. Revenue recognized for the three- and nine-month periods ended September 30, 2018 included $7.4 million and $10.8$2.5 million, respectively, that were included in the contract liability balance at the beginning of each period.
We report the net contract asset or contract liability position on a contract-by-contract basis at the end of each reporting period.
Performance Obligations
As of September 30, 2019, $833.8March 31, 2020, $677.7 million related to unsatisfied performance obligations was expected to be recognized as revenue in the future, with $114.5 million in 2019, $443.2$392.2 million in 2020, and $276.1$219.5 million in 2021 and $66.0 million in 2022 and thereafter. These amounts include fixed consideration and estimated variable consideration for both wholly and partially unsatisfied performance obligations, including mobilization and demobilization fees. These amounts are derived from the specific terms of our contracts, and the expected timing for revenue recognition is based on the estimated start date and duration of each contract according to the information known at September 30, 2019.March 31, 2020.
For the three- and nine-monththree-month periods ended September 30,March 31, 2020 and 2019, and 2018, revenues recognized from performance obligations satisfied (or partially satisfied) in previous periods were immaterial.
Contract Fulfillment Costs
Contract fulfillment costs consist of costs incurred in fulfilling a contract with a customer. Our contract fulfillment costs primarily relate to costs incurred for mobilization of personnel and equipment at the beginning of a contract and costs incurred for demobilization at the end of a contract. Mobilization costs are deferred and amortized ratably over the contract term (including anticipated contract extensions) based on the pattern of the provision of services to which the contract fulfillment costs relate. Demobilization costs are recognized when incurred at the end of the contract. Deferred contract costs are reflected as “Deferred costs,” a component of “Other current assets” and “Other assets, net” onin the accompanying condensed consolidated balance sheets (Note 3). Our deferred contract costs totaled $47.1$37.1 million at September 30, 2019March 31, 2020 and $65.9$42.9 million at December 31, 2018.2019. For the three- and nine-monththree-month periods ended September 30,March 31, 2020 and 2019, we recorded $7.7$9.2 million and $23.6 million, respectively, related to amortization of deferred contract costs existing at the beginning of each period. For the three- and nine-month periods ended September 30, 2018, we recorded $8.5 million and $25.6$7.7 million, respectively, related to amortization of deferred contract costs existing at the beginning of each period. There were no associated impairment losses for any period presented.
For additional information regarding revenue recognition, see Notes 2 and 1012 to our 20182019 Form 10-K.
Note 1011 — Earnings Per Share
We have shares of restricted stock issued and outstanding that are currently unvested. Shares of restricted stock are considered participating securities because holders of shares of unvested restricted stock are entitled to the same liquidation and dividend rights as the holders of our unrestricted common stock. We are required to compute basic and diluted earnings per share (“EPS”) under the two-class method in periods in which we have earnings. Under the two-class method, the undistributed earnings for each period are allocated based on the participation rights of both common shareholders and the 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. 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 obligated to share in such losses.
The presentation of basic EPS on the face of the accompanying condensed consolidated statements of operations is computed by dividing net income or loss by the weighted average shares of our common stock outstanding. The calculation of diluted EPS is similar to that for basic EPS, except that the denominator includes dilutive common stock equivalents and the numerator excludes the effects of dilutive common stock equivalents, if any. The computations of the numerator (income) and denominator (shares) to derive the basic and diluted EPS amounts presented on the face of the accompanying condensed consolidated statements of operations are as follows (in thousands):
|
| | | | | | | | | | | | | |
| Three Months Ended September 30, 2019 | | Three Months Ended September 30, 2018 |
| Income | | Shares | | Income | | Shares |
Basic: | | | | | | | |
Net income attributable to common shareholders | $ | 31,695 |
| | | | $ | 27,121 |
| | |
Less: Undistributed earnings allocated to participating securities | (261 | ) | | | | (260 | ) | | |
Accretion of redeemable noncontrolling interests | (25 | ) | | | | — |
| | |
Net income available to common shareholders, basic | $ | 31,409 |
| | 147,575 |
| | $ | 26,861 |
| | 146,700 |
|
| | | | | | | |
| | | | | | | |
Diluted: | | | | | | | |
Net income available to common shareholders, basic | $ | 31,409 |
| | 147,575 |
| | $ | 26,861 |
| | 146,700 |
|
Effect of dilutive securities: | | | | | | | |
Share-based awards other than participating securities | — |
| | 779 |
| | — |
| | 264 |
|
Undistributed earnings reallocated to participating securities | 1 |
| | — |
| | — |
| | — |
|
Net income available to common shareholders, diluted | $ | 31,410 |
| | 148,354 |
| | $ | 26,861 |
| | 146,964 |
|
|
| | | | | | | | | | | | | |
| Three Months Ended March 31, 2020 | | Three Months Ended March 31, 2019 |
| Income | | Shares | | Income | | Shares |
Basic: | | | | | | | |
Net income (loss) attributable to common shareholders | $ | (11,938 | ) | | | | $ | 1,318 |
| | |
Less: Undistributed earnings allocated to participating securities | — |
| | | | (12 | ) | | |
Accretion of redeemable noncontrolling interests | (2,086 | ) | | | | — |
| | |
Net income (loss) available to common shareholders, basic | $ | (14,024 | ) | | 148,863 |
| | $ | 1,306 |
| | 147,421 |
|
| | | | | | | |
| | | | | | | |
Diluted: | | | | | | | |
Net income (loss) available to common shareholders, basic | $ | (14,024 | ) | | 148,863 |
| | $ | 1,306 |
| | 147,421 |
|
Effect of dilutive securities: | | | | | | | |
Share-based awards other than participating securities | — |
| | — |
| | — |
| | 330 |
|
Net income (loss) available to common shareholders, diluted | $ | (14,024 | ) | | 148,863 |
| | $ | 1,306 |
| | 147,751 |
|
We had a net loss for the three-month period ended March 31, 2020. Accordingly, our diluted EPS calculation for this period excluded any assumed exercise or conversion of common stock equivalents. These common stock equivalents were excluded because they were deemed to be anti-dilutive, meaning their inclusion would have reduced the reported net loss per share in the applicable periods. Shares that otherwise would have been included in the diluted per share calculations assuming we had earnings are as follows (in thousands):
|
| | | | | | | | | | | | | |
| Nine Months Ended September 30, 2019 | | Nine Months Ended September 30, 2018 |
| Income | | Shares | | Income | | Shares |
Basic: | | | | | | | |
Net income attributable to common shareholders | $ | 49,867 |
| | | | $ | 42,345 |
| | |
Less: Undistributed earnings allocated to participating securities | (435 | ) | | | | (407 | ) | | |
Accretion of redeemable noncontrolling interests | (43 | ) | | | | — |
| | |
Net income available to common shareholders, basic | $ | 49,389 |
| | 147,506 |
| | $ | 41,938 |
| | 146,679 |
|
| | | | | | | |
| | | | | | | |
Diluted: | | | | | | | |
Net income available to common shareholders, basic | $ | 49,389 |
| | 147,506 |
| | $ | 41,938 |
| | 146,679 |
|
Effect of dilutive securities: | | | | | | | |
Share-based awards other than participating securities | — |
| | 580 |
| | — |
| | 82 |
|
Undistributed earnings reallocated to participating securities | 2 |
| | — |
| | — |
| | — |
|
Net income available to common shareholders, diluted | $ | 49,391 |
| | 148,086 |
| | $ | 41,938 |
| | 146,761 |
|
|
| | |
| Three Months Ended |
| March 31, 2020 |
| |
Diluted shares (as reported) | 148,863 |
|
Share-based awards | 722 |
|
Total | 149,585 |
|
TheIn addition, the following potentially dilutive shares related to the 2022 Notes the 2023 Notes and the 20322023 Notes were excluded from the diluted EPS calculation as they were anti-dilutive (in thousands):
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 | 2020 | | 2019 |
| | | | | | | | | | |
2022 Notes | 8,997 |
| | 8,997 |
| | 8,997 |
| | 8,997 |
| 8,997 |
| | 8,997 |
|
2023 Notes | 13,202 |
| | 13,202 |
| | 13,202 |
| | 9,381 |
| 13,202 |
| | 13,202 |
|
2032 Notes (1) | — |
| | — |
| | — |
| | 701 |
| |
| |
(1) | The 2032 Notes were fully redeemed in May 2018. |
Note 1112 — Employee Benefit Plans
Long-Term Incentive Plan
We currently have 1 active long-term incentive plan: the 2005 Long-Term Incentive Plan, as amended and restated (the “2005 Incentive Plan”). On May 15, 2019, our shareholders approved an amendment to and restatement of the 2005 Incentive Plan to: (i) authorize 7.0 million additional shares for issuance pursuant to our equity incentive compensation strategy, (ii) establish a maximum award limit applicable to independent members of our Board of Directors (our “Board”) under the 2005 Incentive Plan, (iii) require, subject to certain exceptions, that all awards under the 2005 Incentive Plan have a minimum vesting or restriction period of one year and (iv) remove certain requirements with respect to performance-based compensation under Section 162(m) of the Internal Revenue Code that were repealed by the U.S. Tax Cuts and Jobs Act (the “2017 Tax Act”). As of September 30, 2019,March 31, 2020, there were 8.57.0 million shares of our common stock available for issuance under the 2005 Incentive Plan. During the nine-monththree-month period ended September 30, 2019,March 31, 2020, the following grants of share-based awards were made under the 2005 Incentive Plan:
|
| | | | | | | | | | | | | |
Date of Grant | | | Shares/ Units | | | | Grant Date Fair Value Per Share/Unit | | | Vesting Period |
| | | | | | | | | | |
January 2, 2019 (1) | | | 688,540 |
| | | | $ | 5.41 |
| | | 33% per year over three years |
January 2, 2019 (2) | | | 688,540 |
| | | | 7.60 |
| | | 100% on January 2, 2022 |
January 2, 2019 (3) | | | 11,841 |
| | | | 5.41 |
| | | 100% on January 1, 2021 |
April 1, 2019 (3) | | | 7,625 |
| | | | 7.91 |
| | | 100% on January 1, 2021 |
July 1, 2019 (3) | | | 8,727 |
| | | | 8.63 |
| | | 100% on January 1, 2021 |
August 1, 2019 (4) | | | 7,151 |
| | | | 8.76 |
| | | 100% on August 1, 2020 |
|
| | | | | | | | | | | | | |
Date of Grant | | | Shares/ Units | | | | Grant Date Fair Value Per Share/Unit | | | Vesting Period |
| | | | | | | | | | |
January 2, 2020 (1) | | | 369,938 |
| | | | $ | 9.63 |
| | | 33% per year over three years |
January 2, 2020 (2) | | | 369,938 |
| | | | 13.15 |
| | | 100% on January 2, 2023 |
January 2, 2020 (3) | | | 5,679 |
| | | | 9.63 |
| | | 100% on January 1, 2022 |
| |
(1) | Reflects grants of restricted stock to our executive officers and select management employees. |
| |
(2) | Reflects grants of performance share units (“PSUs”) to our executive officers and select management employees. 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 PSU awards and the minimum amount being 0. |
| |
(3) | Reflects grants of restricted stock to certain independent members of our Board of Directors who have elected to take their quarterly fees in stock in lieu of cash. |
| |
(4) | Reflects a grant of restricted stock made to a new independent member of our Board upon her joining our Board. |
Compensation cost for restricted stock is the product of the grant date fair value of each share and the number of shares granted and is recognized over the applicable vesting period on a straight-line basis. Forfeitures are recognized as they occur. For the three- and nine-monththree-month periods ended September 30,March 31, 2020 and 2019, $1.2$1.1 million and $4.9 million respectively, were recognized as share-based compensation related to restricted stock. For the three- and nine-month periods ended September 30, 2018, $1.5 million and $4.5$1.3 million, respectively, were recognized as share-based compensation related to restricted stock.
The estimated fair value of PSUs is determined using a Monte Carlo simulation model. PSUs granted prior to 2017 could bewere settled in either cash or shares of our common stock and were accounted for as liability awards. BeginningPSUs granted beginning in 2017 PSUs granted are to be settled solely in shares of our common stock and therefore are accounted for as equity awards. Compensation cost for PSUs that are accounted for as equity awards is measured based on the estimated grant date fair value and recognized over the vesting period on a straight-line basis as an increase to equity. For the three- and nine-monththree-month periods ended September 30,March 31, 2020 and 2019, $1.2$1.1 million and $3.9$1.3 million, respectively, were recognized as share-based compensation related to PSUs. ForIn January 2020, based on the three- and nine-month periods ended September 30, 2018, $6.3 million and $11.5 million, respectively, were recognized as share-based compensation related to PSUs. The liability balance for previously unvested PSUsperformance of our common stock over a three-year period, 589,335 equity PSU awards granted in January 2016 was $11.1 million2017 vested at December 31, 2018, which we settled200% and resulted in cash when those PSUs vested in January 2019.the delivery of 1,178,670 shares of our common stock with a total market value of $11.4 million.
Additionally inIn 2020 and 2019, and 2018, we granted fixed-value cash awards of $4.6$4.7 million and $5.2$4.6 million, respectively, to select management employees under the 2005 Incentive Plan. The value of fixed valuethese cash awards is recognized on a straight-line basis over a vesting period of three years. For the three- and nine-monththree-month periods ended September 30,March 31, 2020 and 2019, $0.8$1.2 million and $2.4 million, respectively, were recognized as compensation cost. For the three- and nine-month periods ended September 30, 2018, $0.5 million and $1.3$0.8 million, respectively, were recognized as compensation cost.
Defined Contribution Plan
We sponsor a defined contribution 401(k) retirement plan. Our discretionary contributions, which were reactivated in April 2019, are in the form of cash and currently consist of a 50% match of each participant’s contribution up to 5% of the participant’s salary.
Employee Stock Purchase Plan
We have an employee stock purchase plan (the “ESPP”). On May 15, 2019, our shareholders approved an amendment to and restatement of the ESPP to: (i) increase the shares authorized for issuance by 1.5 million shares and (ii) delegate to an internal administrator the authority to establish the maximum shares purchasable during a purchase period. As of September 30, 2019, 2.0March 31, 2020, 1.9 million shares were available for issuance under the ESPP. The ESPP currently has a purchase limit of 260 shares per employee per purchase period.
For more information regarding our employee benefit plans, including the 2005 Incentive Plan and the ESPP, see Note 1214 to our 20182019 Form 10-K.
Note 1213 — Business Segment Information
We have 3 reportable business segments: Well Intervention, Robotics and Production Facilities. Our U.S., U.K. and Brazil well intervention operating segments are aggregated into the Well Intervention business segment for financial reporting purposes. Our Well Intervention reportable segment includes our vessels and/or equipment used to perform well intervention services primarily in the Gulf of Mexico, Brazil, the North Sea and West Africa. Our well intervention vessels include the Q4000, the Q5000, the Q7000, the Seawell, the Well Enhancer, and the chartered Siem Helix 1 and Siem Helix 2 vessels. Our well intervention equipment includes IRSs and SILs, some of which we provide on a stand-alone basis. Our Robotics segment includes ROVs, trenchers and a ROVDrill, which are designed to complement offshore construction and well intervention services 3and offshore construction to both the oil and gas and the renewable energy markets. Our Robotics segment also includes 2 robotics support vessels under long-term charter: the Grand Canyon,charter, the Grand Canyon II and the Grand Canyon III, andas well as spot vessels, including the Ross Candies, which is under a flexible charter agreement. Our Production Facilities segment includes the HP I, the HFRS, our ownership interest in Independence Hub (Note 4) and our ownership of certain oil and gas properties that we acquired from Marathon Oil in January 2019 (Note 13)2). All material intercompany transactions between the segments have been eliminated.
We evaluate our performance based on operating income of each reportable segment. Certain financial data by reportable segment are summarized as follows (in thousands):
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 | 2020 | | 2019 |
Net revenues — | | | | | | | | | | |
Well Intervention | $ | 170,206 |
| | $ | 154,441 |
| | $ | 451,511 |
| | $ | 445,769 |
| $ | 140,652 |
| | $ | 122,231 |
|
Robotics | 51,909 |
| | 54,340 |
| | 136,396 |
| | 120,569 |
| 35,258 |
| | 39,041 |
|
Production Facilities | 13,777 |
| | 15,877 |
| | 44,651 |
| | 48,541 |
| 15,541 |
| | 15,253 |
|
Intercompany eliminations | (23,283 | ) | | (12,083 | ) | | (51,398 | ) | | (33,417 | ) | (10,430 | ) | | (9,702 | ) |
Total | $ | 212,609 |
| | $ | 212,575 |
| | $ | 581,160 |
| | $ | 581,462 |
| $ | 181,021 |
| | $ | 166,823 |
|
| | | | | | | | | | |
Income (loss) from operations — | | | | | | | | | | |
Well Intervention | $ | 37,689 |
| | $ | 34,427 |
| | $ | 74,002 |
| | $ | 82,774 |
| $ | (5,692 | ) | | $ | 9,641 |
|
Robotics | 8,876 |
| | 5,601 |
| | 7,921 |
| | (12,818 | ) | (2,824 | ) | | (3,904 | ) |
Production Facilities | 3,050 |
| | 6,694 |
| | 11,907 |
| | 20,919 |
| 3,643 |
| | 4,405 |
|
Segment operating income | 49,615 |
| | 46,722 |
| | 93,830 |
| | 90,875 |
| |
Segment operating income (loss) | | (4,873 | ) | | 10,142 |
|
Goodwill impairment (1) | | (6,689 | ) | | — |
|
Corporate, eliminations and other | (10,617 | ) | | (15,345 | ) | | (31,491 | ) | | (35,842 | ) | (9,465 | ) | | (9,873 | ) |
Total | $ | 38,998 |
| | $ | 31,377 |
| | $ | 62,339 |
| | $ | 55,033 |
| $ | (21,027 | ) | | $ | 269 |
|
| |
(1) | Relates to goodwill associated with our STL acquisition (Note 6). |
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 are as follows (in thousands):
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 | 2020 | | 2019 |
| | | | | | | | | | |
Well Intervention (1) | $ | 15,318 |
| | $ | 4,379 |
| | $ | 28,355 |
| | $ | 10,546 |
| $ | 3,304 |
| | $ | 3,225 |
|
Robotics | 7,965 |
| | 7,704 |
| | 23,043 |
| | 22,871 |
| 7,126 |
| | 6,477 |
|
Total | $ | 23,283 |
| | $ | 12,083 |
| | $ | 51,398 |
| | $ | 33,417 |
| $ | 10,430 |
| | $ | 9,702 |
|
| |
(1) | Amounts in the three- and nine-month periods ended September 30, 2019 included $10.6 million and $15.9 million, respectively, associated with P&A work on the Droshky wells for our Production Facilities segment (Notes 2 and 13). Upon completion of the P&A work Marathon Oil is contractually obligated to remit payment to us. |
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, most notably the majority of our cash and cash equivalents. The following table reflects total assets by reportable segment (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| | | | | | |
Well Intervention | $ | 2,133,205 |
| | $ | 1,916,638 |
| $ | 2,134,796 |
| | $ | 2,180,180 |
|
Robotics | 183,125 |
| | 147,602 |
| 136,845 |
| | 151,478 |
|
Production Facilities | 159,225 |
| | 120,845 |
| 140,079 |
| | 142,624 |
|
Corporate and other | 137,956 |
| | 162,645 |
| 102,431 |
| | 122,449 |
|
Total | $ | 2,613,511 |
| | $ | 2,347,730 |
| $ | 2,514,151 |
| | $ | 2,596,731 |
|
Note 1314 — Asset Retirement Obligations
Our assetAsset retirement obligations (“AROs”) are recorded at fair value and consist of estimated costs for subsea infrastructure P&A activities. The estimatedactivities associated with our oil and gas properties, which costs are discounted to present value using a credit-adjusted risk-free discount rate. After its initial recognition, an ARO liability is increased for the passage of time as accretion expense, which is a component of our depreciation and amortization expense. An ARO liability may also change based on revisions in estimated costs and/or timing to settle the obligations.
The following table describes the changes in our AROs (both current and long-term) (in thousands):
|
| | | |
AROs at January 1, 2020 | $ | 28,258 |
|
Accretion expense | 676 |
|
AROs at March 31, 2020 | $ | 28,934 |
|
|
| | | |
AROs at January 1, 2019 | $ | — |
|
Liability incurred during the period (1) | 53,294 |
|
Liability settled during the period | (15,944 | ) |
Accretion expense | 1,770 |
|
AROs at September 30, 2019 | $ | 39,120 |
|
| |
(1) | In connection with the acquisition on January 18, 2019 of certain assets related to the Droshky Prospect (Note 2), we assumed the AROs for the required P&A of those assets in exchange for agreed-upon amounts to be paid by Marathon Oil as the P&A work is completed. We initially recognized $53.3 million of ARO liability, $50.8 million of receivables and $2.5 million of acquired property for this transaction. |
Note 1415 — Commitments and Contingencies and Other Matters
Commitments Related to Our Fleet
We have long-term charter agreements with Siem Offshore AS (“Siem”) for the Siem Helix1 and Siem Helix2 vessels used in connection with our contracts with Petróleo Brasileiro S.A. (“Petrobras”) to perform well intervention work offshore Brazil. The initial term of the charter agreements with Siem is for seven years from the respective vessel delivery dates with options to extend. We have long-term charter agreements for theGrand Canyon, Grand Canyon II and Grand Canyon III vessels for use in our robotics operations. The charter agreements expire in October 2019 for the Grand Canyon, in April 2021 for the Grand Canyon II and in May 2023 for the Grand Canyon III.
In September 2013, we entered into a contract for the constructionQ7000 in November 2019 and the vessel commenced operations in Nigeria in January 2020. With the delivery of a newbuild semi-submersible well intervention vessel, the Q7000, to be built to North Sea standards. Pursuant to the contract and subsequent amendments, 20% of the contract price was paid upon the signing of the contract, 20% was paid in each of 2016, 2017 and 2018, and the remaining 20% is due upon the delivery of the vessel. Weall significant capital commitments have informed the shipyard of our intent to take delivery of the vessel in November 2019. At September 30, 2019, our total investment in the Q7000 was $446.4 million, including $276.8 million of installment payments to the shipyard. The vessel is currently in the final preparation phase for work expected to commence in early 2020.been completed.
Contingencies and Claims
We believe that there are currently no contingencies that would have a material adverse effect on our financial position, results of operations and cash flows.
Litigation
We are involved in various legal proceedings, some involving claims for personal injury under the General Maritime Laws of the United States and the Jones Act. In addition, from time to time we receive other claims, such as contract and employment-related disputes, in the normal course of business.
Note 1516 — Statement of Cash Flow Information
We define cash and cash equivalents as cash and all highly liquid financial instruments with original maturities of three months or less. We classify cash as restricted when there are legal or contractual restrictions for its withdrawal. As of March 31, 2020, we had restricted cash of $52.4 million, which serves as collateral for one project-related letter of credit and is expected to be restricted for less than one year. The following table provides supplemental cash flow information (in thousands):
| | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | 2020 | | 2019 |
| | | | | | |
Interest paid, net of interest capitalized | $ | 2,404 |
| | $ | 6,620 |
| $ | 4,785 |
| | $ | 1,604 |
|
Income taxes paid | 7,535 |
| | 4,699 |
| 2,584 |
| | 2,704 |
|
Our non-cash investing activities include the acquisition of property and equipment for which payment has not been made. These non-cash capital additions totaled $14.0$5.2 million at September 30, 2019March 31, 2020 and $9.9$10.2 million at December 31, 2018.2019.
Note 17 — Allowance for Credit Losses
We estimate current expected credit losses on our accounts receivable at each reporting date. We estimate current expected credit losses based on our credit loss history, adjusted for current factors including global economic and business conditions, oil and gas industry and market conditions, customer mix, contract payment terms and past due accounts receivable.
The following table sets forth the activity in our allowance for credit losses (in thousands):
|
| | | |
| Allowance for Credit Losses |
| |
Balance at December 31, 2019 | $ | — |
|
Initial adoption of ASU 2016-13 (Note 1) | 785 |
|
Provision for current expected credit losses | 586 |
|
Balance at March 31, 2020 | $ | 1,371 |
|
Note 1618 — 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 approaches 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, receivables, accounts payable, long-term debt and derivative instruments. The carrying amount of cash and cash equivalents, trade and other current receivables as well as accounts payable approximates fair value due to the short-term nature of these instruments. The fair value of our derivative instruments (Note 17)19) 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. The fair value of our interest rate swaps is calculated as the discounted cash flows of the difference between the rate fixed by the hedging instrument and the LIBOR forward curve over the remaining term of the hedging instrument. The fair value of our foreign currency exchange contracts is calculated as the discounted cash flows of the difference between the fixed payment specified by the hedging instrument and the expected cash inflow of the forecasted transaction using a foreign currency forward curve. These modeling techniques require us to make estimations of future prices, price correlation, volatility and liquidity based on market data. Our actual results may differ from our estimates, and these differences could be positive or negative. The following tables provide additional information relating to those financial instruments measured at fair value on a recurring basis (in thousands):
|
| | | | | | | | | | | | | | | | | |
| Fair Value at September 30, 2019 | | |
| Level 1 | | Level 2 | | Level 3 | | Total | | Valuation Approach |
Assets: | | | | | | | | | |
Interest rate swaps | $ | — |
| | $ | 108 |
| | $ | — |
| | $ | 108 |
| | (c) |
| | | | | | | | | |
Liabilities: | | | | | | | | | |
Foreign exchange contracts — hedging instruments | — |
| | 1,089 |
| | — |
| | 1,089 |
| | (c) |
Foreign exchange contracts — non-hedging instruments | — |
| | 1,634 |
| | — |
| | 1,634 |
| | (c) |
Total net liability | $ | — |
| | $ | 2,615 |
| | $ | — |
| | $ | 2,615 |
| | |
|
| | | | | | | | | | | | | | | | | |
| Fair Value at December 31, 2018 | | |
| Level 1 | | Level 2 | | Level 3 | | Total | | Valuation Approach |
Assets: | | | | | | | | | |
Interest rate swaps | $ | — |
| | $ | 1,064 |
| | $ | — |
| | $ | 1,064 |
| | (c) |
| | | | | | | | | |
Liabilities: | | | | | | | | | |
Foreign exchange contracts — hedging instruments | — |
| | 6,211 |
| | — |
| | 6,211 |
| | (c) |
Foreign exchange contracts — non-hedging instruments | — |
| | 3,984 |
| | — |
| | 3,984 |
| | (c) |
Total net liability | $ | — |
| | $ | 9,131 |
| | $ | — |
| | $ | 9,131 |
| | |
|
| | | | | | | | | | | | | | | | | |
| Fair Value at March 31, 2020 | | |
| Level 1 | | Level 2 | | Level 3 | | Total | | Valuation Approach |
Liabilities: | | | | | | | | | |
Interest rate swaps | $ | — |
| | $ | 26 |
| | $ | — |
| | $ | 26 |
| | (c) |
Total liability | $ | — |
| | $ | 26 |
| | $ | — |
| | $ | 26 |
| | |
|
| | | | | | | | | | | | | | | | | |
| Fair Value at December 31, 2019 | | |
| Level 1 | | Level 2 | | Level 3 | | Total | | Valuation Approach |
Assets: | | | | | | | | | |
Interest rate swaps | $ | — |
| | $ | 44 |
| | $ | — |
| | $ | 44 |
| | (c) |
| | | | | | | | | |
Liabilities: | | | | | | | | | |
Foreign exchange contracts — hedging instruments | — |
| | 401 |
| | — |
| | 401 |
| | (c) |
Foreign exchange contracts — non-hedging instruments | — |
| | 601 |
| | — |
| | 601 |
| | (c) |
Total net liability | $ | — |
| | $ | 958 |
| | $ | — |
| | $ | 958 |
| | |
The principal amount and estimated fair value of our long-term debt are as follows (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| Principal Amount (1) | | Fair Value (2) (3) | | Principal Amount (1) | | Fair Value (2) (3) | Principal Amount (1) | | Fair Value (2) (3) | | Principal Amount (1) | | Fair Value (2) (3) |
| | | | | | | | | | | | | | |
Term Loan (previously scheduled to mature June 2020) | $ | — |
| | $ | — |
| | $ | 33,693 |
| | $ | 33,314 |
| |
Term Loan (matures December 2021) | 34,125 |
| | 33,698 |
| | — |
| | — |
| $ | 32,375 |
| | $ | 30,797 |
| | $ | 33,250 |
| | $ | 32,959 |
|
Nordea Q5000 Loan (matures April 2020) | 98,214 |
| | 98,214 |
| | 125,000 |
| | 122,500 |
| |
Nordea Q5000 Loan (matures January 2021) (4) | | 80,357 |
| | 80,257 |
| | 89,286 |
| | 89,398 |
|
MARAD Debt (matures February 2027) | 63,610 |
| | 68,972 |
| | 70,468 |
| | 74,406 |
| 60,054 |
| | 62,293 |
| | 63,610 |
| | 68,643 |
|
2022 Notes (mature May 2022) | 125,000 |
| | 126,094 |
| | 125,000 |
| | 114,298 |
| 125,000 |
| | 78,594 |
| | 125,000 |
| | 134,225 |
|
2023 Notes (mature September 2023) | 125,000 |
| | 146,719 |
| | 125,000 |
| | 114,688 |
| 125,000 |
| | 78,125 |
| | 125,000 |
| | 162,188 |
|
Total debt | $ | 445,949 |
| | $ | 473,697 |
| | $ | 479,161 |
| | $ | 459,206 |
| $ | 422,786 |
| | $ | 330,066 |
| | $ | 436,146 |
| | $ | 487,413 |
|
| |
(1) | Principal amount includes current maturities and excludes the related unamortized debt discount and debt issuance costs. See Note 67 for additional disclosures on our long-term debt. |
| |
(2) | The estimated fair value of the 2022 Notes and the 2023 Notes was determined using Level 1 fair value inputs under the market approach. The fair value of the term loans,Term Loan, the Nordea Q5000 Loan and the MARAD Debt was estimated using Level 2 fair value inputs under the market approach, which 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. |
| |
(3) | The principal amount and estimated fair value of the 2022 Notes and the 2023 Notes are for the entire instrument inclusive of the conversion feature reported in shareholders’ equity. |
| |
(4) | The maturity date of the Nordea Q5000 was extended from April 2020 to January 2021 as a result of an amendment to the Nordea Credit Agreement in March 2020 (Note 7). |
Note 1719 — Derivative Instruments and Hedging Activities
Our business is 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 mitigate the impact of market risk exposure related to variable interest rates and foreign currency exchange rates. To reduce the impact of these risks on earnings and increase the predictability of our cash flows, from time to time we enter into certain derivative contracts, including interest rate swaps and foreign currency exchange contracts. All derivative instruments are reflected in the accompanying condensed consolidated balance sheets at fair value.
We engage solely in cash flow hedges. Cash flow hedges are entered into to hedge the variability of cash flows related to a forecasted transaction or to be received or paid related to a recognized asset or liability. Changes in the fair value of derivative instruments that are designated as cash flow hedges are reported in OCI. These changes are subsequently reclassified into earnings when the hedged transactions affect earnings. Changes in the fair value of a derivative instrument that does not qualify for hedge accounting are recorded in earnings in the period in which the change occurs.
For additional information regarding our accounting for derivative instruments and hedging activities, see Notes 2 and 1821 to our 20182019 Form 10-K.
Interest Rate Risk
From time to time, we enter into interest rate swaps to stabilize cash flows related to our long-term variable interest rate debt. In June 2015, we entered into interest rate swap contracts to fix the interest rate on $187.5 million of the Nordea Q5000 Loan (Note 6)7). These swap contracts, which are settled monthly, began in June 2015 and extend through April 2020. Our interest rate swap contracts qualify for cash flow hedge accounting treatment. Changes in the fair value of interest rate swaps are reported in accumulated OCI (net of tax). These changes are subsequently reclassified into earnings when the anticipated interest is recognized as interest expense.
Foreign Currency Exchange Rate Risk
Because we operate in various regions around the world, we conduct a portion of our business in currencies other than the U.S. dollar. We enter into foreign currency exchange contracts from time to time to stabilize expected cash outflows related to our vessel chartersforecasted transactions that are denominated in foreign currencies.
In February 2013, we entered into foreign currency exchange contracts to hedge our foreign currency exposure associated with the Grand Canyon II and Grand Canyon III charter payments denominated in Norwegian kroner through July 2019 and February 2020, respectively. Unrealized losses associated with ourChanges in the fair value of foreign currency exchange contracts that qualify for hedge accounting treatment are includedreported in accumulated OCI (net of tax). These changes are subsequently reclassified into earnings when the forecasted payments are made. Changes in unrealized losses associated with the fair value of foreign currency exchange contracts that aredo not designatedqualify as cash flow hedges are reflectedrecognized immediately in earnings within “Other expense, net” in the accompanying condensed consolidated statements of operations.
Quantitative Disclosures Relating to Derivative Instruments
The following table presents the balance sheet location and fair value of our derivative instruments that were designated as hedging instruments (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| Balance Sheet Location | | Fair Value | | Balance Sheet Location | | Fair Value | Balance Sheet Location | | Fair Value | | Balance Sheet Location | | Fair Value |
Asset Derivative Instruments: | | | | | | | | |
Interest rate swaps | Other current assets | | $ | 108 |
| | Other current assets | | $ | 863 |
| Other current assets | | $ | — |
| | Other current assets | | $ | 44 |
|
Interest rate swaps | Other assets, net | | — |
| | Other assets, net | | 201 |
| |
| | | $ | — |
| | $ | 44 |
|
| | $ | 108 |
| | $ | 1,064 |
| | | | |
| | | | | | | | |
Liability Derivative Instruments: | | | | | | | | |
Foreign exchange contracts | Accrued liabilities | | $ | 1,089 |
| | Accrued liabilities | | $ | 5,857 |
| |
Interest rate swaps | | Accrued liabilities | | $ | 26 |
| | Accrued liabilities | | $ | — |
|
Foreign exchange contracts | Other non-current liabilities | | — |
| | Other non-current liabilities | | 354 |
| Accrued liabilities | | — |
| | Accrued liabilities | | 401 |
|
| | $ | 1,089 |
| | $ | 6,211 |
| | $ | 26 |
| | $ | 401 |
|
The following table presents the balance sheet location and fair value of our derivative instruments that were not designated as hedging instruments (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| Balance Sheet Location | | Fair Value | | Balance Sheet Location | | Fair Value | Balance Sheet Location | | Fair Value | | Balance Sheet Location | | Fair Value |
Liability Derivative Instruments: | | | | | | | | |
Foreign exchange contracts | Accrued liabilities | | $ | 1,634 |
| | Accrued liabilities | | $ | 3,454 |
| Accrued liabilities | | $ | — |
| | Accrued liabilities | | $ | 601 |
|
Foreign exchange contracts | Other non-current liabilities | | — |
| | Other non-current liabilities | | 530 |
| |
| | $ | 1,634 |
| | $ | 3,984 |
| | $ | — |
| | $ | 601 |
|
The following tables present the impact that derivative instruments designated as hedging instruments had on our accumulated OCI (net of tax) and our condensed consolidated statements of operations (in thousands). We estimate that as of September 30, 2019, $0.8 million of net losses in accumulated OCI associated with our derivative instruments is expected to be reclassified into earnings within the next 12 months.:
| | | | Unrealized Gain (Loss) Recognized in OCI | | Unrealized Loss Recognized in OCI |
| | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended March 31, |
| | 2019 | | 2018 | | 2019 | | 2018 | | 2020 | | 2019 |
| | | | | | | | | | | | |
Foreign exchange contracts | | $ | (280 | ) | | $ | (164 | ) | | $ | (338 | ) | | $ | (35 | ) | | $ | (54 | ) | | $ | (34 | ) |
Interest rate swaps | | 6 |
| | 76 |
| | (363 | ) | | 874 |
| | (42 | ) | | (115 | ) |
| | $ | (274 | ) | | $ | (88 | ) | | $ | (701 | ) | | $ | 839 |
| | $ | (96 | ) | | $ | (149 | ) |
| | | Location of Gain (Loss) Reclassified from Accumulated OCI into Earnings | | Gain (Loss) Reclassified from Accumulated OCI into Earnings | Location of Gain (Loss) Reclassified from Accumulated OCI into Earnings | | Gain (Loss) Reclassified from Accumulated OCI into Earnings |
| | Three Months Ended September 30, | | Nine Months Ended September 30, | | Three Months Ended March 31, |
| | 2019 | | 2018 | | 2019 | | 2018 | | 2020 | | 2019 |
| | | | | | | | | | | | |
Foreign exchange contracts | Cost of sales | | $ | (1,197 | ) | | $ | (1,957 | ) | | $ | (5,460 | ) | | $ | (5,538 | ) | Cost of sales | | $ | (455 | ) | | $ | (2,078 | ) |
Interest rate swaps | Net interest expense | | 151 |
| | 158 |
| | 593 |
| | 305 |
| Net interest expense | | 28 |
| | 232 |
|
| | $ | (1,046 | ) | | $ | (1,799 | ) | | $ | (4,867 | ) | | $ | (5,233 | ) | | $ | (427 | ) | | $ | (1,846 | ) |
The following table presents the impact that derivative instruments not designated as hedging instruments had on our condensed consolidated statements of operations (in thousands):
|
| | | | | | | | | | | | | | | | | |
| Location of Loss Recognized in Earnings | | Loss Recognized in Earnings |
| | Three Months Ended September 30, | | Nine Months Ended September 30, |
| | 2019 | | 2018 | | 2019 | | 2018 |
| | | | | | | | | |
Foreign exchange contracts | Other expense, net | | $ | (371 | ) | | $ | (83 | ) | | $ | (413 | ) | | $ | (26 | ) |
| | | $ | (371 | ) | | $ | (83 | ) | | $ | (413 | ) | | $ | (26 | ) |
|
| | | | | | | | | |
| Location of Loss Recognized in Earnings | | Loss Recognized in Earnings |
| | Three Months Ended March 31, |
| | 2020 | | 2019 |
| | | | | |
Foreign exchange contracts | Other expense, net | | $ | (81 | ) | | $ | (40 | ) |
| | | $ | (81 | ) | | $ | (40 | ) |
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
FORWARD-LOOKING STATEMENTS AND ASSUMPTIONS
This Quarterly Report on Form 10-Q contains or incorporates by reference various statements that contain forward-looking information regarding Helix and represent our current expectations and beliefs concerningor forecasts of future events. This forward-looking information is intended to be covered by the safe harbor for “forward-looking statements” provided by the Private Securities Litigation Reform Act of 1995 as set forth in Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements included herein or incorporated herein by reference herein that are predictive in nature, that depend upon or refer to future events or conditions, or that use terms and phrases such as “achieve,” “anticipate,” “believe,” “estimate,” “budget,” “expect,” “forecast,” “plan,” “project,” “propose,” “strategy,” “predict,” “envision,” “hope,” “intend,” “will,” “continue,” “may,” “potential,” “should,” “could” and similar terms and phrases are forward-looking statements although not all forward-looking statements contain such identifying words. Included in forward-looking statements are, among other things:
statements regarding our business strategy and any other business plans, forecasts or objectives, any or all of which are subject to change;
statements regarding projections of revenues, gross margins, expenses, earnings or losses, working capital, debt and liquidity, or other financial items;
statements regarding our backlog and commercial contracts and rates thereunder;
statements regarding our ability to enter into and/or perform commercial contracts, including the scope, timing and outcome of those contracts;
| |
• | statements regarding the acquisition, construction, completion, upgrades to or maintenance of vessels, systems or equipment and any anticipated costs or downtime related thereto, including the construction, completion and mobilization of the Q7000;statements regarding the ongoing COVID-19 pandemic and the recent oil price decline, and their respective effects and results, our protocols and plans, the continuation of our current backlog, the spot market, our cost reduction plans and our ability to manage current changes; statements regarding the acquisition, construction, completion, upgrades to or maintenance of vessels, systems or equipment and any anticipated costs or downtime related thereto; |
statements regarding any financing transactions or arrangements, or our ability to enter into such transactions or arrangements;
statements regarding potential legislative, governmental, regulatory, administrative or other public body actions, requirements, permits or decisions;
statements regarding our trade receivables and their collectability;
statements regarding potential developments, industry trends, performance or industry ranking;
statements regarding general economic or political conditions, whether international, national or in the regional or local markets in which we do business;
statements regarding our ability to retain our senior management and other key employees;
statements regarding the underlying assumptions related to any projection or forward-looking statement; and
any other statements that relate to non-historical or future information.
Although we believe that the expectations reflected in our forward-looking statements are reasonable and are based on reasonable assumptions, they do involve risks, uncertainties and other factors that could cause actual results to differ materially from those in the forward-looking statements. These factors include:
the results and effects of the ongoing COVID-19 pandemic and the recent oil price decline and actions by customers, suppliers and partners with respect thereto;
the impact of domestic and global economic conditions and the future impact of such conditions on the oil and gas industry and the demand for our services;
the general impact of oil and gas price fluctuations and the cyclical nature of the oil and gas industry;
the impact of any potential cancellation, deferral or modification of our work or contracts by our customers;
the ability to effectively bid and perform our contracts, including the impact of equipment problems or failure;
the impact of the imposition by our customers of rate reductions, fines and penalties with respect to our operating assets;
unexpected future capital expenditures, including the amount and nature thereof;
the effectiveness and timing of completion of our vessel and/or system upgrades and major maintenance items;
unexpected delays in the delivery, chartering or customer acceptance, and terms of acceptance, of our assets;
the effects of our indebtedness, our ability to comply with debt covenants and our ability to reduce capital commitments;
the results of our continuing efforts to control costs and improve performance;
the success of our risk management activities;
the effects of competition;
the availability of capital (including any financing) to fund our business strategy and/or operations;
the impact of current and future laws and governmental regulations, including tax and accounting developments, such as the 2017U.S. Tax Act;Cuts and Jobs Act and the CARES Act and regulations thereunder;
the impact of the U.K. to potentially’s exit from the European Union, known as Brexit, on our business, operations and financial condition, which is unknown at this time;
the effect of adverse weather conditions and/or other risks associated with marine operations;
the impact of foreign currency exchange controls, potential illiquidity of those currencies and exchange rate fluctuations;
the effectiveness of our current and future hedging activities;
the potential impact of a loss of one or more key employees; and
the impact of general, market, industry or business conditions.
Our actual results could also differ materially from those anticipated in any forward-looking statements as a result of a variety of factors, including those described under Item 1A. “Risk Factors” in this Quarterly Report, and Item 1A. “Risk Factors” and Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our 20182019 Form 10-K. AllShould one or more of the risks or uncertainties described in this Quarterly Report occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements attributablestatements.
We caution you not to us or persons actingplace undue reliance on our behalf are expressly qualified in their entirety by these risk factors.the forward-looking statements. Forward-looking statements are only as of the date they are made, and other than as required under the securities laws, we assume no obligation to update or revise these forward-looking statements, all of which are expressly qualified by the statements in this section, or provide reasons why actual results may differ. All forward-looking statements, expressed or implied, included in this Quarterly Report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. We urge you to carefully review and consider the disclosures made in this Quarterly Report and our reports filed with the SEC and incorporated by reference in our 2019 Form 10-K that attempt to advise interested parties of the risks and factors that may affect our business.
EXECUTIVE SUMMARY
Our Business Strategy
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 believe that focusing on these services should deliver favorable long-term financial returns. From time to time, we may make strategic investments that expand our service capabilities and/orWith the regions in which we operate, or add capacity to existing services in our key operating regions. We expect our well intervention fleet to expand with the completion and delivery in November 2019 and the commencement of operations in January 2020 of the Q7000, a newbuild semi-submersible vessel. Chartering newerour well intervention fleet currently includes seven purpose-built well intervention vessels, with additional capabilities, such assix IRSs, three SILs and one Riserless Open-water Abandonment Module (“ROAM”). Our robotics equipment currently includes 44 work-class ROVs, four trenchers and one ROVDrill. We also charter ROV support vessels on both long-term and spot bases to facilitate our ROV and trenching operations. Our well intervention and robotic operations are geographically dispersed throughout the three Grand Canyon vessels, should enable our robotics business to better serve the needs of our customers. From a longer-term perspective we also expect to benefit from our fixed fee agreement forworld. Our Production Facilities segment includes the HP I, a dynamically positioned floating production vessel that processes production from the Phoenix field forHFRS and several wells and related infrastructure associated with the field operator, until at least June 1, 2023. With the acquisition of certain oil and gas properties from Marathon Oil in January 2019, we expect improved utilization of our well intervention fleet in the Gulf of Mexico as we perform the P&A of the acquired assets as our schedule permits, subject to regulatory timelines.Droshky Prospect.
In January 2015, Helix, OneSubsea LLC, OneSubsea B.V.,Our alliance with Schlumberger Technology Corporation, Schlumberger B.V. and Schlumberger Oilfield Holdings Ltd. entered into a Strategic Alliance Agreement and related agreements for the parties to design, develop, manufacture, promote, market and sell on a global basis integrated equipment and services for subsea well intervention. The alliance leverages the parties’ capabilities to provide a unique, fully integrated offering to clients, combining marine support with well access and control technologies. We and OneSubseaSchlumberger jointly developed a 15,000 working p.s.i. intervention riser system (“15K IRS”), each owning a 50% interest. The 15K IRS, which was completed and placed into service in January 2018. In October 2016, we2018, and OneSubsea launched the development of our first Riserless Open-water Abandonment Module (“ROAM”), each owning a 50% interest. Final acceptance testing on the ROAM, has been completed and the systemwhich is currently expected to be available to customers in 2020.customers.
Economic Outlook and Industry Influences
Demand for our services is primarily influenced by the condition of the oil and gas industry, and in particular, the willingness of oil and gas companies to spend on operational activities and capital projects. The performance of our business is also largely dependent on the prevailing market prices for oil and natural gas, which are impacted by domestic and global economic conditions, hydrocarbon production and capacity, geopolitical issues, weather, global health, and several other factors, including:
worldwide economic activity and general economic and business conditions, including available access to global capital and capital markets;
the global supply and demand for oil and natural gas;
political and economic uncertainty and geopolitical unrest, including regional conflicts and economic and political conditions in the Middle East and other oil-producing regions;
actions taken by OPEC and/or OPEC+, including actions such as the Organization of Petroleum Exporting Countries;oil price war during the first quarter 2020;
the availability and discovery rate of new oil and natural gas reserves in offshore areas;
the exploration and production of onshore shale oil and natural gas;
the cost of offshore exploration for and production and transportation of oil and natural gas;
the level of excess production capacity;
the ability of oil and gas companies to generate funds or otherwise obtain external capital for capital projects and production operations;
the sale and expiration dates of offshore leases in the U.S. and overseas;globally;
technological advances affecting energy exploration, production, transportation and consumption;
potential acceleration of the development of alternative fuels;
shifts in end-customer preferences toward fuel efficiency and the use of natural gas;gas or renewable energy alternatives;
weather conditions, natural disasters, and natural disasters;epidemic and pandemic diseases, including the ongoing COVID-19 pandemic;
environmental and other governmental regulations; and
domestic and international tax laws, regulations and policies.
West Texas IntermediateCrude oil prices declined significantly in 2014 and have been volatile fluctuatingsince then. Brent crude oil prices fluctuated between $50$53 and $60$75 per barrel throughout most ofduring 2019 before declining precipitously in the first nine months of 2019. Volatility inquarter 2020 to lows below $20 per barrel due to the ongoing COVID-19 pandemic as well as the price war among OPEC+ nations during the first quarter 2020. Low oil prices and imbalancethe volatility and uncertainty in the supply and demand for oil create uncertainty inprices have caused oil and gas explorationoperators recently to drastically reduce spending (both operational activities and production activities. For instance, an increase in oilcapital spending), which has decreased the demand and gas exploration and production activities (shale oil production in particular) is expected when major oil producing countries including the U.S. increase output as a result of rising oil prices. Increased supply without adequate levels of increase in demand, however, may weaken oil prices and industry prospects. The resulting industry environment may discourage oil and gas companies from making longer-term investments inrates for services provided by all offshore exploration and production as well as other offshore operational activities. Increased competition for limited offshore oil and gas projects has driven down rates thatservices providers. Historically, drilling rig contractors are charging for their services, which affects us, as drilling rigs historically have been the asset class used for offshore well intervention work.work, and our customers have used drilling rigs on existing long-term contracts to perform well intervention work instead of new drilling activities. This rig overhang, combined with lower volumes of work continues to affectfor drilling rig contractors, affects the utilization and/or rates we can achieve for our assets. Volatileassets and services. Furthermore, additional volatile and uncertain macroeconomic conditions in some regions and countries around the world, such as West Africa, Brazil, China and the U.K. following Brexit, may have a direct and/or indirect impact on our existing contracts and contracting opportunities and may introduce further currency volatility into our operations and/or financial results.
ManyWe saw improvements in 2019 as compared to 2018 and expected to see a continued recovery as we entered 2020. Rig overhang had reduced, and customer activity and oil prices had recovered to some extent. However, that recovery has now been halted with the ongoing COVID-19 pandemic as well as the OPEC+ price war during the first quarter 2020. While the full impact of these recent events, including the duration of the decrease in economic activity due to COVID-19 and the resulting impact on the demand and price of oil, is unknown, we expect that the industry may be depressed through 2021. We are seeing and expect to continue to see operators reducing spending and deferring work, asserting claims of force majeure and/or cancelling contracts and rig contractors lowering prices, stacking rigs, furloughing employees, and recognizing losses. These developments also have impacted, and are expected to continue to impact, many other aspects of our industry and the global economy, including limiting access to and use of capital across various sources and markets, disrupting supply chains and increasing costs, and negatively affecting human capital resources including complicating offshore crew changes due to health and travel restrictions as well as the overall health of the global workforce.
The COVID-19 pandemic and the OPEC+ price war have resulted in a significant decrease in the price of oil and caused significant disruption and uncertainty in the oil and gas market. While these events did not materially impact our operating results or financial condition during the first quarter 2020, we did incur related impairment losses and our customers have begun to reduce their spending, which we anticipate will reduce the demand for our services at least in the near term and perhaps longer. Additionally, these events have created challenges with our supply chain and human capital resources, including challenges with offshore crew changes due to travel restrictions and quarantine measures. While these market disruptions may be temporary, we cannot reliably estimate the duration of the COVID-19 pandemic or current market conditions, or the ultimate impact they will have on our financial position, results of operations and cash flows.
Although this sustained period of market weakness and volatility has been exacerbated by the ongoing COVID-19 pandemic and the OPEC+ price war, over the longer term we expect oil and gas companies areto increasingly focusingfocus on optimizing production of their existing subsea wells. As oil and gas companies re-assess and focus their budgetary spend allocations, we expect that it may be weighted towards production enhancement activities rather than exploration projects as enhancement is less expensive per incremental barrel of oil than new exploration. Moreover, as the subsea tree base expands and ages, the demand for P&A services should persist. We believe that we have a competitive advantage in terms of performing well intervention services efficiently. Furthermore, we believe that as oil and gas companies begin to increase overall spending levels, it likely will be weighted towards production enhancement activities rather than exploration projects. Our well intervention and robotics operations are intended to service the life span of an oil and gas field as well as to provide P&A services at the end of the life of a field as required by governmental regulations. Thus, weWe believe that fundamentals for our business remain favorable over the longer term as the need to prolong well life in oil and gas production is aand safely decommission end of life wells are primary driverdrivers of demand for our services.
Our current strategy is to be positioned for future market recovery while managing through a sustained period of weak activity. This strategybelief is based on multiple factors, including: (1) the need to extend the life of subsea wells is significant to the commercial viability of the wells as P&A costs are considered; (2) our services offer commercially viable alternatives for reducing the finding and development costs of reserves as compared to new drilling as well as extending and enhancing the commercial life of subsea wells; and (3) in past cycles, well intervention and workover have been some of the first activities to recover, and in a prolonged market downturn are important to the commercial viability of deepwater wells. We could see the beginnings of an upturn in the demand for our services in the Gulf of Mexico, which are primarily driven by three factors: (1) long-term rig contracts are not being renewed thus removing some of the rig overhang that was considered by our customers to be a sunk cost; (2) previously deferred work on aging wells is less likely to be further deferred as well performance declines; and (3) North America customer spending shifts from unconventional onshore oil and gas to conventional offshore development and enhancement as returns from onshore investment opportunities diminish.
Business Activity Summary
On January 16, 2019, we renewed the agreements that provide various operators with access to the HFRS for well control purposes through March 31, 2020 on newly agreed-upon rates and terms. These agreements automatically renew on an annual basis absent proper notice of termination.
On January 18, 2019, we acquired from Marathon Oil several wells and related infrastructure associated with the Droshky Prospect located in offshore Gulf of Mexico Green Canyon Block 244. As part of the transaction, Marathon Oil will pay us agreed-upon amounts for the required P&A of the acquired assets, which we can perform as our schedule permits, subject to regulatory timelines. There is limited production associated with two wells that were acquired as part of the transaction.
On May 29, 2019, we acquired a 70% controlling interest in STL, an Aberdeen-based subsea engineering company that specializes in the design and manufacture of subsea pressure control equipment, including well intervention, well control and subsea control systems.
RESULTS OF OPERATIONS
We have three reportable business segments: Well Intervention, Robotics and Production Facilities. All material intercompany transactions between the segments have been eliminated in our condensed consolidated financial statements, including our consolidated results of operations.Backlog
We seek to provide services and methodologies that we believe are critical to maximizing production economics. Our services cover the lifecycle of an offshore oil or gas field. We provide services primarily in deepwater in the Gulf of Mexico, Brazil, North Sea, Asia Pacific and West Africa regions. In addition to serving the oil and gas market, our Robotics assets are contracted for the development of renewable energy projects (wind farms). As of September 30, 2019,March 31, 2020, our consolidated backlog that is supported by written agreements or contracts totaled $834$678 million, of which $115$392 million is expected to be performed over the remainder of 2019.2020. The substantial majority of our backlog is associated with our Well Intervention business segment. As of September 30, 2019,March 31, 2020, our well intervention backlog was $627$471 million, including $92$306 million expected to be performed over the remainder of 2019.2020. Our contract with BP to provide well intervention services with our Q5000 semi-submersible vessel, our agreements with Petrobras to provide well intervention services offshore Brazil with the Siem Helix 1 and Siem Helix 2 chartered vessels, and our fixed fee agreement for the HP I represent approximately 86%85% of our total backlog as of September 30, 2019.March 31, 2020. Backlog is not necessarily a reliable indicator of revenues derived from these contracts as services may be added or subtracted; contracts may be renegotiated, deferred, canceled and in many cases modified while in progress; and reduced rates, fines and penalties may be imposed by our customers. Furthermore, our contracts are in certain cases cancelable without penalty. If there are cancellation fees, the amount of those fees can be substantially less than the rates we would have generated had we performed the contract.
RESULTS OF OPERATIONS
We have three reportable business segments: Well Intervention, Robotics and Production Facilities. All material intercompany transactions between the segments have been eliminated in our condensed consolidated financial statements, including our consolidated results of operations.
Non-GAAP Financial Measures
A non-GAAP financial measure is generally defined by the SEC as a numerical measure of a company’s historical or future performance, financial position or cash flows that includes or excludes amounts from the most directly comparable measure under GAAP. Non-GAAP financial measures should be viewed in addition to, and not as an alternative to, our reported results prepared in accordance with GAAP. Users of this financial information should consider the types of events and transactions that are excluded from these measures.
We measure our operating performance based on EBITDA and free cash flow. EBITDA and free cash flow are non-GAAP financial measures that are commonly used but are not recognized accounting terms under GAAP. We use EBITDA and free cash flow to monitor and facilitate internal evaluation of the performance of our business operations, to facilitate external comparison of our business results to those of others in our industry, to analyze and evaluate financial and strategic planning decisions regarding future investments and acquisitions, to plan and evaluate operating budgets, and in certain cases, to report our results to the holders of our debt as required by our debt covenants. We believe that our measures of EBITDA and free cash flow provide useful information to the public regarding our operating performance and ability to service debt and fund capital expenditures and may help our investors understand and compare our results to other companies that have different financing, capital and tax structures. Other companies may calculate their measures of EBITDA, Adjusted EBITDA and free cash flow differently from the way we do, which may limit their usefulness as comparative measures. EBITDA, Adjusted EBITDA and free cash flow should not be considered in isolation or as a substitute for, but instead are supplemental to, income from operations, net income, cash flows from operating activities, or other income or cash flow data prepared in accordance with GAAP.
We define EBITDA as earnings before income taxes, net interest expense, gain or loss on extinguishment of long-term debt, net other income or expense, and depreciation and amortization expense. Non-cash impairment losses on goodwill and other long-lived assets and gains and losses on equity investments are also added back if applicable. To arrive at our measure of Adjusted EBITDA, we exclude the gain or loss on disposition of assets and the provision for current expected credit losses, if any. In addition, we include realized losses from foreign currency exchange contracts not designated as hedging instruments and other than temporary loss on note receivable, which are excluded from EBITDA as a component of net other income or expense. We define free cash flow as cash flows from operating activities less capital expenditures, net of proceeds from sale of assets. In the following reconciliation, we provide amounts as reflected in our accompanying condensed consolidated financial statements unless otherwise footnoted.noted.
Other companies may calculate their measures of EBITDA, Adjusted EBITDA and free cash flow differently from the way we do, which may limit their usefulness as comparative measures. EBITDA, Adjusted EBITDA and free cash flow should not be considered in isolation or as a substitute for, but instead are supplemental to, income from operations, net income, cash flows from operating activities, or other income or cash flow data prepared in accordance with GAAP. The reconciliation of our net income to EBITDA and Adjusted EBITDA is as follows (in thousands):
| | | Three Months Ended September 30, | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | | 2019 | | 2018 | 2020 | | 2019 |
| | | | | | | | | | |
Net income | $ | 31,622 |
| | $ | 27,121 |
| | $ | 49,763 |
| | $ | 42,345 |
| |
Net income (loss) | | $ | (13,928 | ) | | $ | 1,318 |
|
Adjustments: | | | | | | | | | | |
Income tax provision | 3,539 |
| | 841 |
| | 6,739 |
| | 1,226 |
| |
Income tax provision (benefit) | | (21,093 | ) | | 324 |
|
Net interest expense | 1,901 |
| | 3,249 |
| | 6,204 |
| | 10,744 |
| 5,746 |
| | 2,098 |
|
Loss on extinguishment of long-term debt | — |
| | 2 |
| | 18 |
| | 1,183 |
| |
Other expense, net | 2,285 |
| | 709 |
| | 2,430 |
| | 3,225 |
| |
Other (income) expense, net | | 10,427 |
| | (1,166 | ) |
Depreciation and amortization | 27,908 |
| | 27,680 |
| | 84,420 |
| | 83,339 |
| 31,598 |
| | 28,509 |
|
Goodwill impairment | | 6,689 |
| | — |
|
EBITDA | 67,255 |
| | 59,602 |
| | 149,574 |
| | 142,062 |
| 19,439 |
| | 31,083 |
|
Adjustments: | | | | | | | | | | |
Gain on disposition of assets, net | — |
| | (146 | ) | | — |
| | (146 | ) | |
Provision for current expected credit losses | | 586 |
| | — |
|
Realized losses from foreign exchange contracts not designated as hedging instruments | (982 | ) | | (820 | ) | | (2,763 | ) | | (2,316 | ) | (682 | ) | | (869 | ) |
Other than temporary loss on note receivable | — |
| | — |
| | — |
| | (1,129 | ) | |
Adjusted EBITDA | $ | 66,273 |
| | $ | 58,636 |
| | $ | 146,811 |
| | $ | 138,471 |
| $ | 19,343 |
| | $ | 30,214 |
|
The reconciliation of our cash flows from operating activities to free cash flow is as follows (in thousands):
| | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | 2020 | | 2019 |
| | | | | | |
Cash flows from operating activities | $ | 89,877 |
| | $ | 150,827 |
| $ | (17,222 | ) | | $ | (34,246 | ) |
Less: Capital expenditures, net of proceeds from sale of assets | (43,086 | ) | | (55,406 | ) | (12,389 | ) | | (11,630 | ) |
Free cash flow | $ | 46,791 |
| | $ | 95,421 |
| $ | (29,611 | ) | | $ | (45,876 | ) |
Comparison of Three Months Ended September 30,March 31, 2020 and 2019 and 2018
The following table details various financial and operational highlights for the periods presented (dollars in thousands):
| | | Three Months Ended September 30, | | Increase/ (Decrease) | Three Months Ended March 31, | | Increase/ (Decrease) |
| 2019 | | 2018 | | Amount | | Percent | 2020 | | 2019 | | Amount | | Percent |
Net revenues — | | | | | | | | | | | | | | |
Well Intervention | $ | 170,206 |
| | $ | 154,441 |
| | $ | 15,765 |
| | 10 | % | $ | 140,652 |
| | $ | 122,231 |
| | $ | 18,421 |
| | 15 | % |
Robotics | 51,909 |
| | 54,340 |
| | (2,431 | ) | | (4 | )% | 35,258 |
| | 39,041 |
| | (3,783 | ) | | (10 | )% |
Production Facilities | 13,777 |
| | 15,877 |
| | (2,100 | ) | | (13 | )% | 15,541 |
| | 15,253 |
| | 288 |
| | 2 | % |
Intercompany eliminations | (23,283 | ) | | (12,083 | ) | | (11,200 | ) | | | (10,430 | ) | | (9,702 | ) | | (728 | ) | | |
| $ | 212,609 |
| | $ | 212,575 |
| | $ | 34 |
| | — | % | $ | 181,021 |
| | $ | 166,823 |
| | $ | 14,198 |
| | 9 | % |
| | | | | | | | | | | | | | |
Gross profit (loss) — | | | | | | | | | | | | | | |
Well Intervention | $ | 41,014 |
| | $ | 37,833 |
| | $ | 3,181 |
| | 8 | % | $ | (1,256 | ) | | $ | 13,510 |
| | $ | (14,766 | ) | | (109 | )% |
Robotics | 10,998 |
| | 8,089 |
| | 2,909 |
| | 36 | % | (467 | ) | | (1,589 | ) | | 1,122 |
| | 71 | % |
Production Facilities | 3,481 |
| | 6,831 |
| | (3,350 | ) | | (49 | )% | 4,207 |
| | 4,771 |
| | (564 | ) | | (12 | )% |
Corporate, eliminations and other | (419 | ) | | (760 | ) | | 341 |
| | | (474 | ) | | (438 | ) | | (36 | ) | | |
| $ | 55,074 |
| | $ | 51,993 |
| | $ | 3,081 |
| | 6 | % | $ | 2,010 |
| | $ | 16,254 |
| | $ | (14,244 | ) | | (88 | )% |
| | | | | | | | | | | | | | |
Gross margin — | | | | | | | | | | | | | | |
Well Intervention | 24% |
| | 24% |
| | | | | (1)% |
| | 11% |
| | | | |
Robotics | 21% |
| | 15% |
| | | | | (1)% |
| | (4)% |
| | | | |
Production Facilities | 25% |
| | 43% |
| | | | | 27% |
| | 31% |
| | | | |
Total company | 26% |
| | 24% |
| | | | | 1% |
| | 10% |
| | | | |
| | | | | | | | | | | | | | |
Number of vessels or robotics assets (1) / Utilization (2) | | | | | | | | | | | | | | |
Well Intervention vessels | 6/97% |
| | 6/91% |
| | | | | 7/72% |
| | 6/74% |
| | | | |
Robotics assets (3) | 51/44% |
| | 54/42% |
| | | | | 49/34% |
| | 52/39% |
| | | | |
Chartered robotics vessels | 4/96% |
| | 4/98% |
| | | | | 6/89% |
| | 4/88% |
| | | | |
| |
(1) | Represents the number of vessels or robotics assets as of the end of the period, including vessels under both short-term and long-term charters, and excluding acquired vessels prior to their in-service dates and vessels or assets disposed of and/or taken out of service. |
| |
(2) | Represents the average utilization rate, which is calculated by dividing the total number of days the vessels or robotics assets generated revenues by the total number of available calendar days in the applicable period. The average utilization rates of chartered robotics vessels during the three-month periods ended September 30,March 31, 2020 and 2019 included 272 and 2018 included 28 and 11384 spot vessel days, respectively, at near full utilization. |
| |
(3) | Consists of ROVs, trenchers and ROVDrill. |
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 are as follows (in thousands):
|
| | | | | | | | | | | |
| Three Months Ended September 30, | | Increase/ (Decrease) |
| 2019 | | 2018 | |
| | | | | |
Well Intervention | $ | 15,318 |
| | $ | 4,379 |
| | $ | 10,939 |
|
Robotics | 7,965 |
| | 7,704 |
| | 261 |
|
| $ | 23,283 |
| | $ | 12,083 |
| | $ | 11,200 |
|
|
| | | | | | | | | | | |
| Three Months Ended March 31, | | Increase/ (Decrease) |
| 2020 | | 2019 | |
| | | | | |
Well Intervention | $ | 3,304 |
| | $ | 3,225 |
| | $ | 79 |
|
Robotics | 7,126 |
| | 6,477 |
| | 649 |
|
| $ | 10,430 |
| | $ | 9,702 |
| | $ | 728 |
|
Net Revenues. Our total net revenues increased by 9% for the three-month period ended September 30, 2019 were consistent with those forMarch 31, 2020 as compared to the same period in 20182019, primarily reflecting a mix of higher revenues from our Well Intervention business segment with the addition of the Q7000, offset in part by lower revenues from our Robotics and Production Facilities business segments, and higher intercompany eliminations.segment.
Our Well Intervention revenues increased by 10%15% for the three-month period ended September 30, 2019March 31, 2020 as compared to the same period in 20182019, primarily reflecting increaseshigher revenues with the commencement of operations of the Q7000 in revenuesNigeria in January 2020 and higher utilization on our North Sea vessels. This revenue increase was partially offset by a reduction in vessel utilization in the Gulf of Mexico, and Brazil, partially offset by lower revenues in the North Sea. In the Gulf of Mexico, the Q4000 generated higher revenues due to higher utilization and a higher number of integrated service projects. IRS rental revenues were also higher in the third quarter of 2019. Revenue increases fromwith both the Q4000 and IRS rental were partially offset by lower revenues from the Q5000 due to lower utilization. Our Well Intervention revenues in the Gulf of Mexicocompleting scheduled regulatory certification inspections during the third quarter of 2019 also included $10.6 million associated with P&A work on the Droshky wells for our Production Facilities segment, for which Marathon Oil remitted payment to us in September 2019. The increase in revenues in Brazil was primarily a result of the Siem Helix2 achieving 99% utilization during the third quarter of 2019 as compared to 90% during the same period in 2018. The decrease in revenues in the North Sea was primarily attributable to lower rates and a weaker British pound as compared to the third quarter of 2018.period.
Robotics revenues decreased by 4%10% for the three-month period ended September 30, 2019March 31, 2020 as compared to the same period in 2018. The2019, primarily reflecting the decrease primarily reflected lowerin trenching activity and spot vessela reduction in ROV, trencher and ROVDrill utilization offset in part by higher rates on our Grand CanyonII chartered vessel and higher ROV utilization in the three-month period ended September 30, 2019 as compared to the same period in 2018.2019. Our results included 42 vessel trenching days during the three months ended March 31, 2020 compared to 133 days during the same period in 2019. These reductions were partially offset by higher spot vessel utilization, which increased to 272 days from 84 days in the prior year period.
Our Production Facilities revenues decreasedincreased by 13%2% for the three-month period ended September 30, 2019March 31, 2020 as compared to the same period in 20182019, primarily reflecting lower revenues from the HFRS during the third quarter of 2019, offset in part byhigher production revenues from the oil and gas properties that we acquired from Marathon Oil in January 2019 (Note 2).
The increase in intercompany eliminations was primarily the result of $10.6 million in revenue that our Well Intervention business segment earned associated with its completion of P&A work on behalf of our Production Facilities segment.
Gross Profit (Loss). Our total gross profit increaseddecreased by 6%88% for the three-month period ended September 30, 2019March 31, 2020 as compared to the same period in 20182019 reflecting higher gross profit generated by our Well Intervention and Robotics business segments, offset in part by lower gross profit in our Production FacilitiesWell Intervention business segment.
The gross profit related to our Well Intervention segment increased by 8% for the three-month period ended September 30, 2019 as compared to the same period in 2018 primarily as a result of higher revenues in the Gulf of Mexico and Brazil, partially offset by lower revenues in the North Sea.
The gross profit related to our RoboticsWell Intervention business segment increaseddecreased by 36%109% for the three-month period ended September 30, 2019March 31, 2020 as compared to the same period in 20182019, primarily reflecting a reduction in vessel utilization in the Gulf of Mexico, with both the Q4000 and the Q5000 completing scheduled regulatory certification inspections during the period, offset in part by the contribution from the Q7000 and higher revenues generatedprofits in the North Sea.
The gross loss related to our Robotics segment decreased by our71% for the three-month period ended March 31, 2020 as compared to the same period in 2019, primarily reflecting a reduction in costs related to the termination of the Grand Canyon II chartered vessel charter in November 2019 and lower costs due to the expiration of the Grand Canyon II hedge in July 2019, of foreign currency exchange contracts to hedge the vessel’s charter payments (Note 17), offset in part by lower spot vessel activity.revenues.
The gross profit related to our Production Facilities segment decreased by 49%12% for the three-month period ended September 30, 2019March 31, 2020 as compared to the same period in 20182019 primarily reflecting revenue decreasessignificantly lower direct costs as the HPI vessel went into regulatory dry dock for recertification during three-month period ended March 31, 2020. The recertification costs are typically deferred and amortized.
Goodwill Impairment. The $6.7 million impairment charge for the HFRS.three-month period ended March 31, 2020 reflects the write-off of the entire goodwill balance associated with STL (Note 6).
Selling, General and Administrative Expenses. Our selling, general and administrative expenses decreasedincreased by $4.7$0.4 million for the three-month period ended September 30, 2019March 31, 2020 as compared to the same period in 2018. The decrease was primarily attributable to compensation costs in the third quarter of 2018 that were related to liability PSU awards, which settled in January 2019 (Note 11).
Net Interest Expense. Our net interest expense decreased by $1.3 million for the three-month period ended September 30, 2019 as compared to the same period in 2018 primarily reflecting higher capitalized interest. Interest on debt used to finance capital projects is capitalized and thus reduces overall interest expense. Capitalized interest totaled $5.1 million for the three-month period ended September 30, 2019 as compared to $3.9 million for the same period in 2018 as a result of the construction and completion of the Q7000.
Other Expense, Net. Net other expense increased by $1.6 million for the three-month period ended September 30, 2019 as compared to the same period in 2018 primarily reflecting a $1.3 million increase in foreign currency transaction losses.
Income Tax Provision. Income tax provision was $3.5 million for the three-month period ended September 30, 2019 as compared to $0.8 million for the same period in 2018. The effective tax rate was 10.1% for the three-month period ended September 30, 2019 as compared to 3.0% for the same period in 2018.2019. The increase was primarily attributable to improvements in profitability in the U.S. year over year (Note 7).
Comparison of Nine Months Ended September 30, 2019 and 2018
The following table details various financial and operational highlights$0.6 million provision for the periods presented (dollars in thousands):
|
| | | | | | | | | | | | | | |
| Nine Months Ended September 30, | | Increase/ (Decrease) |
| 2019 | | 2018 | | Amount | | Percent |
Net revenues — | | | | | | | |
Well Intervention | $ | 451,511 |
| | $ | 445,769 |
| | $ | 5,742 |
| | 1 | % |
Robotics | 136,396 |
| | 120,569 |
| | 15,827 |
| | 13 | % |
Production Facilities | 44,651 |
| | 48,541 |
| | (3,890 | ) | | (8 | )% |
Intercompany eliminations | (51,398 | ) | | (33,417 | ) | | (17,981 | ) | | |
| $ | 581,160 |
| | $ | 581,462 |
| | $ | (302 | ) | | — | % |
| | | | | | | |
Gross profit (loss) — | | | | | | | |
Well Intervention | $ | 84,761 |
| | $ | 93,554 |
| | $ | (8,793 | ) | | (9 | )% |
Robotics | 14,546 |
| | (5,294 | ) | | 19,840 |
| | 375 | % |
Production Facilities | 13,152 |
| | 21,282 |
| | (8,130 | ) | | (38 | )% |
Corporate, eliminations and other | (1,197 | ) | | (1,669 | ) | | 472 |
| | |
| $ | 111,262 |
| | $ | 107,873 |
| | $ | 3,389 |
| | 3 | % |
| | | | | | | |
Gross margin — | | | | | | | |
Well Intervention | 19% |
| | 21% |
| | | | |
Robotics | 11% |
| | (4)% |
| | | | |
Production Facilities | 29% |
| | 44% |
| | | | |
Total company | 19% |
| | 19% |
| | | | |
| | | | | | | |
Number of vessels or robotics assets (1) / Utilization (2) | | | | | | | |
Well Intervention vessels | 6/88% |
| | 6/84% |
| | | | |
Robotics assets (3) | 51/42% |
| | 54/37% |
| | | | |
Chartered robotics vessels | 4/92% |
| | 4/76% |
| | | | |
| |
(1) | Represents the number of vessels or robotics assetscurrent expected credit losses as of the end of the period, including vessels under both short-term and long-term charters, and excluding acquired vessels prior to their in-service dates and vessels disposed of and/or taken out of service. |
| |
(2) | Represents the average utilization rate, which is calculated by dividing the total number of days the vessels or robotics assets generated revenues by the total number of available calendar days in the applicable period. The average utilization rates of chartered robotics vessels during the nine-month periods ended September 30, 2019 and 2018 included 137 and 208 spot vessel days, respectively, at near full utilization. |
| |
(3) | Consists of ROVs, trenchers and ROVDrill. |
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 are as follows (in thousands):
|
| | | | | | | | | | | |
| Nine Months Ended September 30, | | Increase/ (Decrease) |
| 2019 | | 2018 | |
| | | | | |
Well Intervention | $ | 28,355 |
| | $ | 10,546 |
| | $ | 17,809 |
|
Robotics | 23,043 |
| | 22,871 |
| | 172 |
|
| $ | 51,398 |
| | $ | 33,417 |
| | $ | 17,981 |
|
Net Revenues. Our total net revenues for the nine-month period ended September 30, 2019 were consistent with those for the same period in 2018 reflecting a mix of higher revenues from our Well Intervention and Robotics business segments, lower revenues from our Production Facilities business segment, and higher intercompany eliminations.
Our Well Intervention revenues increased by 1% for the nine-month period ended September 30, 2019 as compared to the same period in 2018, primarily reflecting higher revenues in the Gulf of Mexico and Brazil, partially offset by lower revenues in the North Sea. The increase in revenues in the Gulf of Mexico was primarily attributable to higher utilization of the Q4000 during the first nine months of 2019 as compared to the same period in 2018. This revenue increase was offset by a reduction in IRS rental revenues during the comparative year-over-year periods. Our Well Intervention revenues in the Gulf of Mexico during the first nine months of 2019 also included $15.9 million associated with P&A work on the Droshky wells for our Production Facilities segment, for which Marathon Oil remitted payment to us in September 2019. The increase in revenues in Brazil was primarily a result of both the Siem Helix1 and the Siem Helix2 improving their utilization during the first nine monthsadoption of 2019. The decreaseASU No. 2016-13 in revenues in the North Sea primarily reflected a weaker British pound and lower rates as compared to the same period in 2018.
Robotics revenues increased by 13% for the nine-month period ended September 30, 2019 as compared to the same period in 2018. The increase primarily reflected higher trenching activities that contributed to increased utilization of our chartered vessels (from 76% during the first nine months of 2018 to 92% during the same period in 2019). Our robotics assets also achieved higher utilization in the first nine months of 2019 as compared to the same period in 2018.
Our Production Facilities revenues decreased by 8% for the nine-month period ended September 30, 2019 as compared to the same period in 2018 primarily reflecting lower revenues from the HFRS during the nine-month period ended September 30, 2019, offset in part by production revenues from the oil and gas properties that we acquired from Marathon Oil in January 20192020 (Note 2).
The increase in intercompany eliminations was primarily the result of $15.9 million in revenue that our Well Intervention business segment earned associated with its completion of P&A work on behalf of our Production Facilities segment.
Gross Profit (Loss). Our total gross profit increased by 3% for the nine-month period ended September 30, 2019 as compared to the same period in 2018 reflecting improvements in our Robotics business segment, offset in part by lower gross profit in our Well Intervention and Production Facilities business segments.
The gross profit related to our Well Intervention business segment decreased by 9% for the nine-month period ended September 30, 2019 as compared to the same period in 2018 primarily reflecting lower IRS rental unit utilization in the Gulf of Mexico as well as reduced operating results in the North Sea, offset in part by improved operating results in Brazil.
Our Robotics segment achieved a gross profit of $14.5 million for the nine-month period ended September 30, 2019 as compared to a gross loss of $5.3 million for the same period in 2018 primarily reflecting higher trenching revenues, with increased utilization for our chartered vessels and our robotics assets, and a reduction in vessel charter costs.
The gross profit related to our Production Facilities segment decreased by 38% for the nine-month period ended September 30, 2019 as compared to the same period in 2018 primarily reflecting revenue decreases for the HFRS.
Selling, General and Administrative Expenses. Our selling, general and administrative expenses decreased by $4.1 million for the nine-month period ended September 30, 2019 as compared to the same period in 2018. The decrease was primarily attributable to compensation costs in the first nine months of 2018 that were related to liability PSU awards, which settled in January 2019 (Note 11)17).
Net Interest Expense. Our net interest expense decreasedincreased by $4.5$3.6 million for the nine-monththree-month period ended September 30, 2019March 31, 2020 as compared to the same period in 20182019, primarily reflecting higherlower capitalized interest and a decrease in interest expense due to a reduction in our overall debt levels.interest. Capitalized interest totaled $15.3$1.2 million for the nine-monththree-month period ended September 30, 2019March 31, 2020 as compared to $11.5$5.0 million for the same period in 20182019 as a result of the construction and completion of the Q7000.
Loss on Extinguishment of Long-Term Debt. The $1.2 million loss for the nine-month period ended September 30, 2018 was attributable to the write-off of the unamortized debt issuance costs related to the prepayment of $61 million of the then-existing term loan in March 2018 and costs associated with our repurchase of $59.3 million in aggregate principal amount of the 2032 Notes (Note 6).
Other Expense,Income (Expense), Net. NetWe reported net other expense decreased by $0.8of $10.4 million for the nine-monththree-month period ended September 30, 2019March 31, 2020 as compared to the same period in 2018 primarily reflecting a $1.1 millionnet other than temporary loss on a note receivable during the nine-month period ended September 30, 2018.
Income Tax Provision. Income tax provision was $6.7 million for the nine-month period ended September 30, 2019 as compared toincome of $1.2 million for the same period in 2018. The effective tax rate was 11.9% for2019, primarily reflecting foreign currency transaction losses in the nine-monththree-month period ended September 30, 2019March 31, 2020 as compared to 2.8%foreign currency transaction gains in the same period in 2019 due to the weakening of the British pound.
Income Tax Provision (Benefit). Income tax benefit was $21.1 million for the three-month period ended March 31, 2020 as compared to an income tax provision of $0.3 million for the same period in 2018.2019. The increaseeffective tax rates for the three-month periods ended March 31, 2020 and 2019 were 60.2% benefit and 19.7% expense, respectively. The variance in the effective tax rate was primarily attributable to improvements in profitability inour carrying back certain net operating losses to prior periods with higher income tax rates as well as the result of the consolidation of certain U.S. year over yearbranch operations with the Helix U.S. consolidated tax group (Note 7)8).
LIQUIDITY AND CAPITAL RESOURCES
Overview
The following table presents certain information useful in the analysis of our financial condition and liquidity (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| | | | | | |
Net working capital | $ | 199,934 |
| | $ | 259,440 |
| $ | 151,048 |
| | $ | 153,508 |
|
Long-term debt (1) | 304,932 |
| | 393,063 |
| 303,584 |
| | 306,122 |
|
Liquidity (2) | 458,971 |
| | 426,813 |
| 331,959 |
| | 379,533 |
|
| |
(1) | Long-term debt does not include the current maturities portion of our long-term debt as that amount is included in net working capital. Long-term debt is also net of unamortized debt discounts and debt issuance costs. See Note 67 for information relating to our long-term debt. |
| |
(2) | Liquidity, as defined by us, is equal to cash and cash equivalents plus available capacity under the Revolving Credit Facility, which capacity is reduced by letters of credit drawn against that facility. Our liquidity at September 30, 2019March 31, 2020 included cash and cash equivalents of $286.3$159.4 million and $172.6 million of available borrowing capacity under the Revolving Credit Facility (Note 6)7). Our liquidity at December 31, 20182019 included cash and cash equivalents of $279.5$208.4 million and $147.4$171.1 million of available borrowing capacity under our then-existing revolving credit facility.the Revolving Credit Facility. |
The carrying amount of our long-term debt, including current maturities, net of unamortized debt discounts and debt issuance costs, is as follows (in thousands):
| | | September 30, 2019 | | December 31, 2018 | March 31, 2020 | | December 31, 2019 |
| | | | | | |
Term Loan (previously scheduled to mature June 2020) | $ | — |
| | $ | 33,321 |
| |
Term Loan (matures December 2021) | 33,687 |
| | — |
| $ | 32,041 |
| | $ | 32,869 |
|
Nordea Q5000 Loan (matures April 2020) | 97,768 |
| | 123,980 |
| |
Nordea Q5000 Loan (matures January 2021) | | 79,959 |
| | 89,031 |
|
MARAD Debt (matures February 2027) | 59,951 |
| | 66,443 |
| 56,639 |
| | 60,073 |
|
2022 Notes (mature May 2022) (1) | 114,848 |
| | 112,192 |
| 116,690 |
| | 115,765 |
|
2023 Notes (mature September 2023) (1) | 107,146 |
| | 104,379 |
| 109,092 |
| | 108,115 |
|
Total debt | $ | 413,400 |
| | $ | 440,315 |
| $ | 394,421 |
| | $ | 405,853 |
|
| |
(1) | The 2022 Notes and the 2023 Notes will increase to their face amounts through accretion of theirthe debt discounts through May 1, 2022 and September 15, 2023, respectively. |
The following table provides summary data from our condensed consolidated statements of cash flows (in thousands):
| | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | 2020 | | 2019 |
Cash provided by (used in): | | | | | | |
Operating activities | $ | 89,877 |
| | $ | 150,827 |
| $ | (17,222 | ) | | $ | (34,246 | ) |
Investing activities | (47,167 | ) | | (55,406 | ) | (12,389 | ) | | (11,956 | ) |
Financing activities | (35,638 | ) | | (35,974 | ) | (18,391 | ) | | (14,055 | ) |
Our current requirements for cash primarily reflect the need to fund our operations and capital spending for our current lines of business and to service our debt. Historically, we have funded our capital program with cash flows from operations, borrowings under credit facilities, and project financing, along with other debt and equity alternatives. As of September 30, 2019, the remaining principal balance of the Nordea Q5000 Loan was classified to current as its maturity date is April 30, 2020. Although we currently have no plans to do so, we have the ability to fund the repayment of the Nordea Q5000 Loan when due with available borrowing capacity under the Revolving Credit Facility.
As a further response toGiven the ongoing COVID-19 pandemic, challenging market conditions and recent market events resulting in industry-wide spending reductions,cuts, we continue to remain focused on maintaining a strong balance sheet and adequate liquidity. Over the near term, we may seekplan to reduce, defer or cancel certain planned capital expenditures.expenditures and reduce our overall cost structures commensurate with our expected level of activities. We believe that our cash on hand, internally generated cash flows and availability under the Revolving Credit Facility will be sufficient to fund our operations and service our debt over at least the next 12 months.
In accordance with the Credit Agreement, the 2022 Notes, the 2023 Notes, the MARAD Debt agreements and the Nordea Credit Agreement, we are required to comply with certain covenants, including with respect to the Credit Agreement, certain financial ratios such as a consolidated interest coverage ratio and various leverage ratios, as well as the maintenance of a minimum cash balance, net worth, working capital and debt-to-equity requirements. The Credit Agreement also contains provisions that limit our ability to incur certain types of additional indebtedness. These provisions effectively prohibit us from incurring additional secured indebtedness or indebtedness guaranteed by us. The Credit Agreement does permit us to incur certain unsecured indebtedness and also provides for our subsidiaries to incur project financing indebtedness (such as the MARAD Debt and the Nordea Q5000 Loan) secured by the underlying asset, provided that such indebtedness is not guaranteed by us. The Credit Agreement also permits Unrestricted Subsidiaries to incur indebtedness provided that it is not guaranteed by us or any of our Restricted Subsidiaries (as defined in the Credit Agreement). As of September 30, 2019 and December 31, 2018, we were in compliance with all of the covenants in our long-term debt agreements.
A prolonged period of weak, or a significant decrease in, industry activity may make it difficult to comply with our covenants and the other restrictions in the agreements governing our debt. Current global and market conditions have increased the potential for that difficulty. Furthermore, during any period of sustained weak economic activity and reduced EBITDA, our ability to fully access the Revolving Credit Facility may be impacted. At September 30, 2019,March 31, 2020, our available borrowing capacity under the Revolving Credit Facility, based on the applicable leverage ratio covenant, was $172.6 million, net of $2.4 million of letters of credit issued under that facility. We currently have no plans or forecasted requirements to borrowdo not anticipate borrowing under the Revolving Credit Facility other than for the issuance of letters of credit. Our ability to comply with loan agreement covenants and other restrictions is affected by economic conditions and other events beyond our control. Our failure to comply with these covenants and other restrictions could lead to an event of default, the possible acceleration of our outstanding debt and the exercise of certain remedies by our lenders, including foreclosure against our collateral.
Subject to the terms of the Credit Agreement, we may borrow and/or obtain letters of credit of up to $25 million under the Revolving Credit Facility. See Note 6 for additional information relating to our long-term debt, including more information regarding the Credit Agreement and related covenants and collateral.
The 2022 Notes and the 2023 Notes can be converted into our common stock by the holders or redeemed by us prior to their stated maturity under certain circumstances specified in the applicable indenture governing the notes. We can settle any conversion in cash, shares of our common stock or a combination thereof.
We repurchased $59.3 million in aggregate principal amount of the 2032 Notes on March 20, 2018 and redeemed the remaining $0.8 million outstanding on May 4, 2018.
Operating Cash Flows
Total cash flows fromused in operating activities decreased by $61.0$17.0 million for the nine-monththree-month period ended September 30, 2019March 31, 2020 as compared to the same period in 20182019 primarily reflecting the timing of cash receipts fromchanges in our customers and other increases in net working capital during the first nine months of 2019 as well as higher regulatory certification costs for our vessels and systems, which included costs related to planned dry docks for three of our vessels.capital.
Investing Activities
Capital expenditures represent cash paid principally for the acquisition, construction, completion, upgrade, modification and refurbishment of long-lived property and equipment such as dynamically positioned vessels, topside equipment and subsea systems. Capital expenditures also include interest on property and equipment under development. Significant (uses) sources (uses) of cash associated with investing activities are as follows (in thousands):
| | | Nine Months Ended September 30, | Three Months Ended March 31, |
| 2019 | | 2018 | 2020 | | 2019 |
Capital expenditures: | | | | | | |
Well Intervention | $ | (44,323 | ) | | $ | (54,845 | ) | $ | (12,263 | ) | | $ | (11,485 | ) |
Robotics | (388 | ) | | (89 | ) | (44 | ) | | — |
|
Production Facilities | (123 | ) | | (113 | ) | — |
| | (2 | ) |
Other | (802 | ) | | (384 | ) | (82 | ) | | (168 | ) |
STL acquisition, net | (4,081 | ) | | — |
| |
Proceeds from sale of assets | 2,550 |
| | 25 |
| — |
| | 25 |
|
Other | | — |
| | (326 | ) |
Net cash used in investing activities | $ | (47,167 | ) | | $ | (55,406 | ) | $ | (12,389 | ) | | $ | (11,956 | ) |
Our capital expenditures above primarily included payments associated with the construction and completion of the Q7000 (see below).
In September 2013, we entered into a contract for the construction of the Q7000, a newbuild semi-submersible well intervention vessel the Q7000,built to be built toU.K. North Sea standards. Pursuant to the contract and subsequent amendments, 20% of the contract price was paid upon the signing of the contract, 20% was paid in each of 2016, 2017 and 2018, and the remaining 20% is duewas paid upon the delivery of the vessel. We have informed the shipyard of our intent to take delivery of the vessel in November 2019. At September 30, 2019,March 31, 2020, our total investment in the Q7000 was $446.4$539.3 million, including $276.8$346.0 million of installment payments to the shipyard. We plan to incur approximately $80 million related to the Q7000 over the remainder of 2019, including the final shipyard payment of $69.2 million. The vessel is currentlycommenced operations in the final preparation phase for work expected to commenceNigeria in earlyJanuary 2020.
Financing Activities
Cash flows from financing activities consist primarily of proceeds from debt and equity transactions and repayments of our long-term debt. Net cash outflows from financing activities of $35.6$18.4 million for the nine-monththree-month period ended September 30, 2019March 31, 2020 primarily reflectedreflect the repayment of $68.2$13.4 million of our indebtedness and $35.0 million in proceeds from the Term Loan (Note 6)7). Net cash outflows from financing activities of $36.0$14.1 million for the nine-monththree-month period ended September 30, 2018March 31, 2019 primarily reflectedreflect the repayment of $156.6$13.3 million of our indebtedness using cash and the net proceeds from the issuance in March 2018 of $125 million of the 2023 Notes (Note 6).indebtedness.
Free Cash Flow
Free cash flow decreasedincreased by $48.6$16.3 million for the nine-monththree-month period ended September 30, 2019March 31, 2020 as compared to the same period in 20182019 primarily attributable to the decreaseincrease in operating cash flows, slightly offset by reduced capital expenditures inflows.
Free cash flow is a non-GAAP financial measure. See “RESULTS OF OPERATIONS” above for the first nine monthsdefinition and calculation of 2019.free cash flow.
Outlook
We anticipate that our capital expenditures, including capitalized interest and regulatory certification costs for our vessels and systems, will approximate $150$38 million for 2019.2020. We believe that cash on hand, internally generated cash flows and availability under the Revolving Credit Facility will provide the capital necessary to continue funding our 2019 capital obligations2020 operating needs and to meet our debt obligations due in 2019. Our estimate of future capital expenditures may change based on various factors. We may seek to reduce the level of our planned capital expenditures given a prolonged industry downturn.2020.
Contractual Obligations and Commercial Commitments
The following table summarizes our contractual cash obligations as of September 30, 2019March 31, 2020 and the scheduled years in which the obligations are contractually due (in thousands):
| | | Total (1) | | Less Than 1 Year | | 1-3 Years | | 3-5 Years | | More Than 5 Years | Total (1) | | Less Than 1 Year | | 1-3 Years | | 3-5 Years | | More Than 5 Years |
| | | | | | | | | | | | | | | | | | |
Term Loan | $ | 34,125 |
| | $ | 3,500 |
| | $ | 30,625 |
| | $ | — |
| | $ | — |
| $ | 32,375 |
| | $ | 3,500 |
| | $ | 28,875 |
| | $ | — |
| | $ | — |
|
Nordea Q5000 Loan | 98,214 |
| | 98,214 |
| | — |
| | — |
| | — |
| 80,357 |
| | 80,357 |
| | — |
| | — |
| | — |
|
MARAD Debt | 63,610 |
| | 7,200 |
| | 15,497 |
| | 17,082 |
| | 23,831 |
| 60,054 |
| | 7,378 |
| | 15,879 |
| | 17,503 |
| | 19,294 |
|
2022 Notes (2) | 125,000 |
| | — |
| | 125,000 |
| | — |
| | — |
| 125,000 |
| | — |
| | 125,000 |
| | — |
| | — |
|
2023 Notes (3) | 125,000 |
| | — |
| | — |
| | 125,000 |
| | — |
| 125,000 |
| | — |
| | — |
| | 125,000 |
| | — |
|
Interest related to debt (4) | 55,365 |
| | 18,620 |
| | 26,941 |
| | 8,207 |
| | 1,597 |
| 46,683 |
| | 18,058 |
| | 22,371 |
| | 5,206 |
| | 1,048 |
|
Property and equipment (5) | 80,261 |
| | 80,261 |
| | — |
| | — |
| | — |
| 5,319 |
| | 5,319 |
| | — |
| | — |
| | — |
|
Operating leases (6)(5) | 405,123 |
| | 110,197 |
| | 193,669 |
| | 94,408 |
| | 6,849 |
| 338,310 |
| | 103,400 |
| | 181,871 |
| | 48,029 |
| | 5,010 |
|
Total cash obligations | $ | 986,698 |
| | $ | 317,992 |
| | $ | 391,732 |
| | $ | 244,697 |
| | $ | 32,277 |
| $ | 813,098 |
| | $ | 218,012 |
| | $ | 373,996 |
| | $ | 195,738 |
| | $ | 25,352 |
|
| |
(1) | Excludes unsecured letters of credit outstanding at September 30, 2019March 31, 2020 totaling $2.4 million. These letters of credit may be issued to support various obligations, such as contractual obligations, contract bidding and insurance activities. |
| |
(2) | Notes mature in May 2022. The 2022 Notes can be converted prior to their stated maturity if the closing price of our common stock for at least 20 days in the period of 30 consecutive trading days ending on the last trading day of the preceding fiscal quarter exceeds $18.06 per share, which is 130% of the conversion price. At September 30, 2019,March 31, 2020, the conversion trigger was not met. See Note 67 for additional information. |
| |
(3) | Notes mature in September 2023. The 2023 Notes can be converted prior to their stated maturity if the closing price of our common stock for at least 20 days in the period of 30 consecutive trading days ending on the last trading day of the preceding fiscal quarter exceeds $12.31 per share, which is 130% of the conversion price. At September 30, 2019,March 31, 2020, the conversion trigger was not met. See Note 67 for additional information. |
| |
(4) | Interest payment obligations were calculated using stated coupon rates for fixed rate debt and interest rates applicable at September 30, 2019March 31, 2020 for variable rate debt. |
| |
(5) | Primarily reflects costs associated with the Q7000, which is currently under completion (Note 14).
|
| |
(6) | Operating leases include vessel charters and facility and equipment leases. At September 30, 2019,March 31, 2020, our commitment related to long-term vessel charters totaled approximately $366.2$299.2 million, of which $147.2$111.5 million iswas related to the non-lease (services) components that are not included in operating lease liabilities on ourin the condensed consolidated balance sheet.sheet as of March 31, 2020. |
CRITICAL ACCOUNTING POLICIESESTIMATES AND ESTIMATESPOLICIES
Our discussion and analysis of our financial condition and results of operations, are based upon ouras reflected in the accompanying condensed consolidated financial statements. We prepare these financial statements and related footnotes, are prepared in conformity with GAAP. As such, we are required to make certain estimates, judgments and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the periods presented. We base our estimates on historical experience, available information and various other assumptions we believe to be reasonable under the circumstances. These estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as our operating environment changes.
For information regarding our critical accounting policiesestimates and estimates,policies, please read our “Critical Accounting PoliciesEstimates and Estimates”Policies” as disclosed in our 20182019 Form 10-K.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
We areAs of March 31, 2020, we were exposed to market risks associated with interest rates and foreign currency exchange rates.
Interest Rate Risk. As of September 30, 2019, $132.3March 31, 2020, $112.7 million of our outstanding debt was subject to floating rates. The interest rate applicable to our variable rate debt may continue to rise, thereby increasing our interest expense and related cash outlay. In June 2015, we entered into various interest rate swap contracts to fix the interest rate on a portion of the Nordea Q5000 Loan. These swap contracts, which are settled monthly, began in June 2015 and extend through April 2020. As of September 30, 2019,March 31, 2020, the interest rate on $73.6$60.3 million of the Nordea Q5000 Loan was hedged. Debt subject to variable rates after considering hedging activities was $58.7$52.4 million. The impact of interest rate risk is estimated using a hypothetical increase in interest rates by 100 basis points for our variable rate long-term debt that is not hedged. Based on this hypothetical assumption, we would have incurred an additional $0.5$0.1 million in interest expense for the nine-monththree-month period ended September 30, 2019.March 31, 2020.
Foreign Currency Exchange Rate Risk. Because we operate in various regions around the world, we conduct a portion of our business in currencies other than the U.S. dollar. As such, our earnings are impacted by movements in foreign currency exchange rates when (i) transactions are denominated in currencies other than the functional currency of the relevant Helix entity, or (ii) the functional currency of our subsidiaries is not the U.S. dollar. In order to mitigate the effects of exchange rate risk in areas outside the United States, we generallyendeavor to pay a portion of our expenses in local currencies to partially offset revenues that are denominated in the same local currencies. In addition, a substantial portion of our contracts provide for collections from customers in U.S. dollars. During
Assets and liabilities of our subsidiaries that do not have the nine-month period ended September 30, 2019, we recognized lossesU.S. dollar as their functional currency are translated using the exchange rates in effect at the balance sheet date, resulting in translation adjustments that are reflected in “Accumulated other comprehensive loss” in the shareholders’ equity section of $2.0 million related to foreign currency transactions in “Other expense, net” in our condensed consolidated statementbalance sheets. For the three-month period ended March 31, 2020, we recorded foreign currency translation losses of operations.$33.6 million to accumulated other comprehensive loss. Deferred taxes have not been provided on foreign currency translation adjustments since we consider our undistributed earnings (when applicable) of our non-U.S. subsidiaries without operations in the U.S. to be permanently reinvested.
When currencies other than the functional currency are to be paid or received, the resulting transaction gain or loss is recognized in the condensed consolidated statements of operations as a component of “Other income (expense), net.” For the three-month period ended March 31, 2020, we recognized foreign currency transaction losses of $10.4 million, primarily related to our subsidiaries in the U.K.
In February 2013, we entered into various foreign currency exchange contracts to hedge our foreign currency exposure with respect to the Grand Canyon II and Grand Canyon III charter payments denominated in Norwegian kroner, which were fully settled through July 2019 and February 2020, respectively.2020. A portion of these foreign currency exchange contracts currently qualifiesqualified for cash flow hedge accounting treatment.
Item 4. Controls and Procedures
(a) Evaluation of disclosure controls and procedures. Our management, with the participation of our principal executive officer and principal financial officer, has evaluated the effectiveness of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, as of September 30, 2019.March 31, 2020. Based on this evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective as of September 30, 2019March 31, 2020 to ensure that information that is required to be disclosed by us in the reports we file or submit under the Exchange Act is (i) recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms; and (ii) accumulated and communicated to our management, as appropriate, to allow timely decisions regarding required disclosure.
(b) Changes in internal control over financial reporting. There have been no changes in our internal control over financial reporting that occurred during the quarter ended September 30, 2019March 31, 2020 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
Part II. OTHER INFORMATION
Item 1. Legal Proceedings
See Part I, Item 1, Note 1415 to the Condensed Consolidated Financial Statements, which is incorporated herein by reference.
Item 1A. Risk Factors
The ongoing COVID-19 pandemic and the recent OPEC+ price war could disrupt our operations and adversely impact our business and financial results.
In March 2020, the World Health Organization classified the outbreak of COVID-19 as a pandemic. The nature of COVID-19 led to worldwide shutdowns and halting of commercial and interpersonal activity, as governments around the world imposed regulations in efforts to control the spread of COVID-19 such as shelter-in-place orders, quarantines, executive orders and similar restrictions. As a result the global economy has been marked by significant slowdown and uncertainty, which has led to a precipitous decline in oil prices in response to demand concerns, further exacerbated by the OPEC+ price war during the first quarter 2020 and global storage considerations. The confluence of these events has resulted in significantly weaker outlook for oil producers and by extension oilfield service companies, including reduced operating and capital budgets as well as market confidence in overall industry viability. We are not currently able to predict the duration or severity of the spread of COVID-19, the OPEC+ price war or the responses thereto, and if economic and industry conditions do not improve, these events will adversely impact our financial condition and results of operations.
The spread of COVID-19 to one or more of our locations, including our vessels, could significantly impact our operations. We have implemented various protocols for both onshore and offshore personnel in efforts to limit the impact of COVID-19, however those may not prove fully successful. The spread of COVID-19 to our onshore workforce could prevent us from supporting our offshore operations, we may experience reduced productivity as our onshore personnel works remotely, and any spread to our key management personnel may disrupt our business. Any outbreak on our vessels may result in the vessel, or some or all of a vessel crew (including customer crew), being quarantined and therefore impede the vessel's ability to generate revenue. We have experienced several instances of COVID-19 among our offshore crew, and although to date we have managed to minimize operational disruption, there can be no guarantee that will remain the case. We have experienced challenges in connection with our offshore crew changes due to health and travel restrictions related to COVID-19, and those challenges and/or restrictions may continue or worsen. We may also experience an increased cybersecurity risk as our onshore personnel work remotely.
Further, each of the decline in global oil demand combined with overall market uncertainty resulting from the ongoing COVID-19 pandemic, along with the recent OPEC+ price war, may continue to impact the demand for our services, the utilization and/or rates we can achieve for our assets and services, and the outlook for our industry in general. Our business is adversely affected by low oil prices, especially the willingness of oil and gas companies to make capital and other expenditures for offshore exploration, development, drilling and production operations, and the persistence of current conditions would negatively impact those companies’ willingness and ability to make those expenditures. In the event one or more of our major customers is adversely affected by COVID-19 or otherwise the current market environment, that may impact our business with them. We may face an increased risk of customers deferring work, asserting claims of force majeure, and/or terminating contracts, or our customers’ inability to make payments or remain solvent. The current environment may make it even more difficult to comply with our covenants and other restrictions in agreements governing our debt, and a lack of confidence in our industry on the part of the financial markets may result in a lack of access to capital, any of which could lead to reduced liquidity, an event of default, the possible acceleration of our repayment of outstanding debt, the exercise of certain remedies by our lenders, or a limited ability or inability to refinance our debt.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
Issuer Purchases of Equity Securities
|
| | | | | | | | | | | | | |
Period | | (a) Total number of shares purchased (1) | | (b) Average price paid per share | | (c) Total number of shares purchased as part of publicly announced program | | (d) Maximum number of shares that may yet be purchased under the program (2) |
July 1 to July 31, 2019 | | — |
| | $ | — |
| | — |
| | 4,707,227 |
|
August 1 to August 31, 2019 | | 2,255 |
| | 7.34 |
| | — |
| | 4,714,378 |
|
September 1 to September 30, 2019 | | — |
| | — |
| | — |
| | 4,743,694 |
|
| | 2,255 |
| | $ | 7.34 |
| | — |
| | |
|
| | | | | | | | | | | | | |
Period | | (a) Total number of shares purchased (1) | | (b) Average price paid per share | | (c) Total number of shares purchased as part of publicly announced program | | (d) Maximum number of shares that may yet be purchased under the program (2) |
January 1 to January 31, 2020 | | 534,698 |
| | $ | 9.58 |
| | — |
| | 6,475,615 |
|
February 1 to February 29, 2020 | | — |
| | — |
| | — |
| | 6,475,615 |
|
March 1 to March 31, 2020 | | — |
| | — |
| | — |
| | 6,475,615 |
|
| | 534,698 |
| | $ | 9.58 |
| | — |
| | |
| |
(1) | Includes shares forfeited in satisfaction of tax obligations upon vesting of restricted shares. |
| |
(2) | Under the terms of our stock repurchase program, the issuance ofwe may repurchase shares to members of our Boardcommon stock in an amount equal to any equity granted to our employees, officers and to certain employees,directors under our share-based compensation plans, including share-based awards under our existing long-term incentive plans and shares issued to our employees under theour ESPP to participating employees (Note 11)12), increasesand such shares increase the number of shares available for repurchase. For additional information regarding our stock repurchase program, see Note 911 to our 20182019 Form 10-K. |
Item 6. Exhibits
|
| | | | |
Exhibit Number | | Description | | Filed or Furnished Herewith or Incorporated by Reference from the Following Documents (Registration or File Number) |
3.1 | | | | |
3.2 | | | | |
4.1 | | | | |
31.1 | | | | |
31.2 | | | | |
32.1 | | | | |
101.INS | | XBRL Instance Document. | | The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document |
101.SCH | | XBRL Schema Document. | | Filed herewith |
101.CAL | | XBRL Calculation Linkbase Document. | | Filed herewith |
101.PRE | | XBRL Presentation Linkbase Document. | | Filed herewith |
101.DEF | | XBRL Definition Linkbase Document. | | Filed herewith |
101.LAB | | XBRL Label Linkbase Document. | | Filed herewith |
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
|
| | | | |
| | | | HELIX ENERGY SOLUTIONS GROUP, INC. (Registrant) |
Date: | October 23, 2019April 24, 2020 | | By: | /s/ Owen Kratz |
| | | | Owen Kratz President and Chief Executive Officer (Principal Executive Officer) |
| | | | |
Date: | October 23, 2019April 24, 2020 | | By: | /s/ Erik Staffeldt |
| | | | Erik Staffeldt Executive Vice President and Chief Financial Officer (Principal Financial Officer) |