Form 8-K

8-K — HELIX ENERGY SOLUTIONS GROUP INC

Accession: 0000866829-26-000011

Filed: 2026-04-23

Period: 2026-04-22

CIK: 0000866829

SIC: 1389 (OIL, GAS FIELD SERVICES, NBC)

Item: Results of Operations and Financial Condition

Item: Regulation FD Disclosure

Item: Financial Statements and Exhibits

Documents

8-K — hlx-20260422x8k.htm (Primary)

EX-99.1 (hlx-20260422xex99d1.htm)

EX-99.2 (hlx-20260422xex99d2.htm)

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8-K

8-K (Primary)

Filename: hlx-20260422x8k.htm · Sequence: 1

HELIX ENERGY SOLUTIONS GROUP, INC._April 22, 2026

0000866829false00008668292026-04-222026-04-22

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Date of Report (Date of earliest event reported): April 22, 2026

HELIX ENERGY SOLUTIONS GROUP, INC.

(Exact name of registrant as specified in its charter)

Minnesota

001-32936

95-3409686

(State or other jurisdiction

of incorporation)

(Commission

File Number)

(IRS Employer

Identification No.)

3505 West Sam Houston Parkway North

Suite 400

Houston, Texas

77043

(Address of principal executive offices)

(Zip Code)

Registrant’s telephone number, including area code: 281-618-0400

NOT APPLICABLE

(Former name or former address, if changed since last report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

☐ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

☐ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

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

Title of each class

Trading Symbol(s)

Name of each exchange on which registered

Common Stock, no par value

HLX

New York Stock Exchange

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

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. ☐

Item 2.02. Results of Operations and Financial Condition.

On April 22, 2026, Helix Energy Solutions Group, Inc. (“Helix”) issued a press release reporting its financial results for the first quarter 2026. The press release is furnished herewith as Exhibit 99.1 and incorporated herein by reference.

Item 7.01. Regulation FD Disclosure.

On April 22, 2026, Helix issued a press release reporting its financial results for the first quarter 2026. In addition, on April 23, 2026, Helix is making a presentation (with slides) to analysts and investors regarding its financial and operating results. Furnished herewith as Exhibits 99.1 and 99.2, respectively, and incorporated herein by reference, are the press release and the slides for the First Quarter 2026 Conference Call Presentation issued by Helix. The presentation materials are also available on the Investor Relations section of Helix’s website, www.helixesg.com.

The information furnished pursuant to Items 2.02 and 7.01, including Exhibits 99.1 and 99.2, shall not be deemed to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and will not be incorporated by reference into any filing under the Securities Act of 1933, as amended, unless specifically identified therein as being incorporated therein by reference.

Item 9.01. Financial Statements and Exhibits.

(d) Exhibits.

Exhibit

Number

Description

99.1

Press Release of Helix Energy Solutions Group, Inc. dated April 22, 2026 reporting financial results for the first quarter 2026.

99.2

First Quarter 2026 Conference Call Presentation.

104

Cover Page Interactive Data File (embedded within the Inline XBRL document).

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 hereunto duly authorized.

Date: April 22, 2026

HELIX ENERGY SOLUTIONS GROUP, INC.

By:

/s/ Erik Staffeldt

Erik Staffeldt

Executive Vice President and

Chief Financial Officer

EX-99.1

Filename: hlx-20260422xex99d1.htm · Sequence: 2

EXHIBIT 99.1

PRESSRELEASE

www.helixesg.com

Helix Energy Solutions Group, Inc.

●

3505 W. Sam Houston Parkway N., Suite 400

●

Houston, TX 77043

●

281-618-0400

●

fax: 281-618-0505

For Immediate Release

26-006

Date: April 22, 2026

Contact:

Erik Staffeldt

Executive Vice President & CFO

Helix Reports First Quarter 2026 Results

HOUSTON, TX – Helix Energy Solutions Group, Inc. (“Helix”) (NYSE: HLX) reported a net loss of $13.4 million, or $(0.09) per diluted share, for the first quarter 2026 compared to net income of $8.3 million, or $0.06 per diluted share, for the fourth quarter 2025 and net income of $3.1 million, or $0.02 per diluted share, for the first quarter 2025. Net income during the fourth quarter 2025 included a non-cash impairment charge for certain of our oil and gas properties of approximately $18.1 million (pre-tax).

Helix reported Adjusted EBITDA1 of $32.3 million for the first quarter 2026 compared to $73.9 million for the fourth quarter 2025 and $52.0 million for the first quarter 2025. The table below summarizes our results of operations:

Summary of Results

($ in thousands, except per share amounts, unaudited)

Three Months Ended

3/31/2026

3/31/2025

12/31/2025

Revenues

287,946

278,064

334,162

Gross Profit

8,828

27,538

50,663

Net Income (Loss)

(13,406)

3,072

8,270

Basic Earnings (Loss) Per Share

(0.09)

0.02

0.06

Diluted Earnings (Loss) Per Share

(0.09)

0.02

0.06

Adjusted EBITDA1

32,262

51,985

73,871

Cash and Cash Equivalents

501,272

369,987

445,196

Net Debt1

(197,511)

(58,878)

(137,201)

Cash Flows from Operating Activities

61,786

16,442

113,163

Free Cash Flow1

58,975

11,954

107,467

Owen Kratz, President and Chief Executive Officer of Helix, stated, “Our first quarter results reflect the expected seasonal slowdown of operations in the North Sea and Gulf of America shelf as well as the costs of the successful workover of our Thunder Hawk field during the quarter. Nonetheless, we generated $59 million of Free Cash Flow and ended the quarter with over half a billion dollars in cash providing Helix with tremendous opportunities. While we face ongoing macro uncertainties and softness in some of the markets we serve, the recent commodity price increases have generated improved demand for our services, and recent government actions in the North Sea have provided a regulatory catalyst to spur decommissioning activities by our customers. Helix continues to expect momentum to build in the offshore market in the latter half of 2026 and into 2027 and is poised to capitalize on those opportunities.”

1 Adjusted EBITDA, Net Debt and Free Cash Flow are non-GAAP measures; see reconciliations below

Segment Information, Operational and Financial Highlights

($ in thousands, unaudited)

Three Months Ended

3/31/2026

3/31/2025

12/31/2025

Revenues:

Well Intervention

209,443

198,374

181,006

Robotics

62,373

51,042

87,332

Shallow Water Abandonment

21,236

16,818

57,555

Production Facilities

18,736

19,837

17,262

Intercompany Eliminations

(23,842)

(8,007)

(8,993)

Total

287,946

278,064

334,162

Income (Loss) from Operations:

Well Intervention

10,857

19,970

12,269

Robotics

7,773

5,347

19,056

Shallow Water Abandonment

(10,730)

(13,441)

8,560

Production Facilities

(7,909)

6,944

3,548

Long-lived asset impairment

—

(18,064)

Corporate / Other / Eliminations

(13,306)

(10,648)

(13,105)

Total

(13,315)

8,172

12,264

Segment Results

Well Intervention

Well Intervention revenues increased $28.4 million, or 16%, during the first quarter 2026 compared to the prior quarter primarily due to increases in the Gulf of America and Brazil. Revenues in the Gulf of America increased with higher utilization and rates on the Q4000. The Q5000 had an approximate two-week maintenance period reducing its utilization that was more than offset by higher project-related revenues with its workover of the Thunder Hawk field owned by our Production Facilities segment. Revenues also increased with our recognition of a full quarter of utilization on the Sea Helix 1, which had lower utilization during the prior quarter as it transitioned to the long-term Petrobras contract. North Sea revenues were unchanged, with revenues on the Seawell, which resumed operations during the first quarter 2026 after being idle during the prior quarter, nearly entirely offset by lower utilization and lower seasonal rates on the Well Enhancer. Overall Well Intervention vessel utilization increased to 82% during the first quarter 2026 compared to 72% during the prior quarter. Well Intervention operating income decreased $1.4 million during the first quarter 2026 compared to the fourth quarter 2025 primarily due to higher project costs associated with the workover of the Thunder Hawk field and vessel reactivation costs and lower margins in the North Sea due to the mix of contracting.

Well Intervention revenues increased $11.1 million, or 6%, during the first quarter 2026 compared to the first quarter 2025. The increase was primarily due to higher utilization on the Q7000, which was fully utilized during the first quarter 2026 compared to operating for six days during the first quarter 2025 following its mobilization to and docking in Brazil. Revenues also increased due to the reactivation of the Seawell in 2026, which was idle throughout 2025, and due to higher project-related rates on the Q5000 during its workover of the Thunder Hawk field for our Production Facilities segment. Revenue increases were partially offset by lower revenues on the Q4000, which generated lower rates compared to higher project-related rates during its operations in Nigeria during the first quarter 2025. Well Intervention operating income decreased $9.1 million during the first quarter 2026 compared to the first quarter 2025 primarily due to lower profits in the Gulf of America, higher operating costs in Brazil, and lower incremental margins in the North Sea and on the Q7000.

Robotics

Robotics revenues decreased $25.0 million, or 29%, during the first quarter 2026 compared to the prior quarter due to the expected seasonally lower vessel, trenching and ROV utilization. During the first quarter we commenced operations with the MV Patriot chartered vessel, which replaced the Glomar Wave after being returned to its owner at the end of the fourth quarter 2025. During the first quarter 2026, total vessel days decreased to 381 days, or 79%, compared to 491, or 91%, during the prior quarter. Integrated vessel trenching decreased to 122 days and trenching on third-party vessels decreased to 90 days, compared to 134 days and 137 days, respectively, during the prior quarter. Offsetting lower vessel trenching was an increase in site clearance operations using our IROV boulder grabs, which generated 110 days of utilization during the first quarter 2026 compared to 100 days during the prior quarter. Overall ROV and trencher utilization decreased to 56% during the first quarter 2026 compared to 58% during the prior quarter. Robotics operating income decreased $11.3 million compared to the prior quarter primarily due to lower revenues.

Robotics revenues increased $11.3 million, or 22%, during the first quarter 2026 compared to the first quarter 2025. Revenue increases were primarily due to higher vessel activities and higher overall ROV utilization, offset partially by fewer trenching days and lower project-related revenues during the first quarter 2026. The first quarter 2026 included 381 total vessel days, or 79%, compared to 244 vessel days, or 67%, during the first quarter 2025. These improvements were offset partially by a reduction in integrated vessel trenching to 122 days during the first quarter 2026 compared to 135 days during the first quarter 2025. Robotics operating income increased $2.4 million during the first quarter 2026 primarily due higher revenues during the first quarter 2026.

Shallow Water Abandonment

Shallow Water Abandonment revenues decreased $36.3 million, or 63%, during the first quarter 2026 compared to the prior quarter. The decrease in revenues was primarily related to lower seasonal operations in the Gulf of America shelf with lower utilization on vessels including the Epic Hedron, and systems during the first quarter 2026. Vessel utilization (excluding heavy lift) decreased to 37% during the first quarter 2026 compared to 52% during the prior quarter. The Epic Hedron heavy lift barge underwent a planned regulatory docking and had no utilization during the first quarter 2026 compared to strong fourth quarter 2025 utilization of 92%. Plug and Abandonment (“P&A”) and Coiled Tubing (“CT”) systems activity decreased to 369 days, or 16% utilization, during the first quarter 2026 compared to 621 days, or 26% utilization, during the prior quarter. Shallow Water Abandonment operating income decreased $19.3 million compared to the prior quarter primarily due to lower revenues during the first quarter 2026.

Shallow Water Abandonment revenues increased $4.4 million, or 26%, during the first quarter 2026 compared to the first quarter 2025 primarily due to higher utilization on our vessels and systems during the first quarter 2026. Vessel utilization (excluding heavy lift), increased to 37% during the first quarter 2026 compared to 31% during the first quarter 2025. Utilization on P&A and CT systems increased to 369 days, or 16%, during the first quarter 2026 compared to 264 days, or 11%, during the first quarter 2025. The Epic Hedron was idle during both the first quarters 2025 and 2026. During the first quarter 2026, two liftboats and three OSVs remained stacked as a cost reduction measure. Shallow Water Abandonment operating income increased $2.7 million in the first quarter 2026 compared to the first quarter 2025 primarily due to higher revenues.

Production Facilities

Production Facilities revenues increased $1.5 million, or 9%, during the first quarter 2026 compared to the prior quarter primarily due to higher oil and gas production and prices from the Droshky field. The Thunder Hawk field was shut in during both the current and prior quarters, but a successful workover was completed on the Thunder Hawk field at the end of the first quarter 2026. Production Facilities generated an operating loss of $7.9 million during the first quarter 2026, a decrease of $11.5 million compared to the prior quarter primarily due to workover costs on the Thunder Hawk field, offset partially by higher revenues, during the first quarter 2026.

Production Facilities revenues decreased $1.1 million, or 6%, during the first quarter 2026 compared to the first quarter 2025 primarily due to lower oil and gas production and prices from the Droshky field. Production Facilities generated an operating loss of $7.9 million during the first quarter 2026, a decrease of $14.9 million compared to the first quarter 2025 primarily due to workover costs on the Thunder Hawk field and lower revenues during the first quarter 2026.

Selling, General and Administrative and Other

Selling, General and Administrative

Selling, general and administrative expenses were $22.1 million, or 7.7% of revenue, during the first quarter 2026 compared to $20.3 million, or 6.1% of revenue, during the prior quarter and $19.4 million, or 7.0% of revenue, during the first quarter 2025. The increase in expenses quarter over quarter was primarily due to higher employee compensation and higher professional service costs during the first quarter 2026.

Other Income and Expense

Other income, net was $0.3 million during the first quarter 2026 compared to other expense, net of $0.5 million during the prior quarter and $0.4 million during the first quarter 2025. Other income and expense, net primarily includes net foreign currency gains and losses related to our international subsidiaries’ foreign currency positions.

Cash Flows

Operating cash flows were $61.8 million during the first quarter 2026 compared to $113.2 million during the prior quarter and $16.4 million during the first quarter 2025. Operating cash flows decreased compared to the prior quarter primarily due lower earnings and higher regulatory certification costs on our vessels and systems, offset partially by higher working capital inflows driven by collections of accounts receivable during the first quarter 2026. Operating cash flows increased compared to the first quarter 2025 primarily due to higher working capital inflows, offset partially by lower earnings during the first quarter 2026. Regulatory certifications for our vessels and systems, which are included in operating cash flows, were $8.9 million during the first quarter 2026 compared to $3.7 million during the prior quarter and $17.9 million during the first quarter 2025.

Capital expenditures, which are included in investing cash flows, totaled $2.8 million during the first quarter 2026 compared to $5.7 million during the prior quarter and $4.5 million during the first quarter 2025.

Free Cash Flow was $59.0 million during the first quarter 2026 compared to $107.5 million during the prior quarter and $12.0 million during the first quarter 2025. (Free Cash Flow is a non-GAAP measure. See reconciliation below.)

Financial Condition and Liquidity

Cash and cash equivalents were $501.3 million at March 31, 2026. Available capacity under our ABL facility at March 31, 2026, was $113.0 million, and total liquidity was $611.7 million, excluding $2.6 million cash pledged toward our ABL facility. Consolidated long-term debt was $303.8 million at March 31, 2026, resulting in negative Net Debt of $197.5 million. (Net Debt is a non-GAAP measure. See reconciliation below.)

* * * * *

Conference Call Information

Further details are provided in the presentation for Helix’s quarterly teleconference to review its first quarter 2026 results (see the Investor Relations page of Helix’s website, www.helixesg.com). The teleconference is scheduled for Thursday, April 23, 2026, at 9:00 a.m. Central Time. Investors and other interested parties wishing to participate in the teleconference should dial 1-800-715-9871 within the United States and 1-646-307-1963 outside the United States. The passcode is “Staffeldt.” A live webcast of the teleconference will be available in a listen-only mode on the Investor Relations section of Helix’s website. A replay of the webcast will be available on Helix’s website shortly after the completion of the event.

About Helix

Helix Energy Solutions Group, Inc., headquartered in Houston, Texas, is an international offshore energy services company that provides specialty services to the offshore energy industry, with a focus on well intervention, robotics and decommissioning operations. Our services are key in supporting a global energy transition by maximizing production of existing oil and gas reserves, decommissioning end-of-life oil and gas fields and supporting renewable energy developments. For more information about Helix, please visit our website at www.helixesg.com.

Non-GAAP Financial Measures

Management evaluates operating performance and financial condition using certain non-GAAP measures, primarily Adjusted EBITDA, Free Cash Flow and Net Debt. We define Adjusted EBITDA as earnings before income taxes, net interest expense, depreciation and amortization expense, net other income or expense, gains or losses on disposition of assets, long-lived asset impairment losses, acquisition and integration costs, gains or losses related to convertible senior notes, the change in fair value of contingent consideration, and the general provision for (release of) current expected credit losses, if any. We define Free Cash Flow as cash flows from operating activities less capital expenditures, net of proceeds from asset sales and insurance recoveries (related to property and equipment), if any. Net Debt is calculated as long-term debt including current maturities of long-term debt less cash and cash equivalents and restricted cash.

We use Adjusted EBITDA, Free Cash Flow and Net Debt 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 Adjusted EBITDA, Free Cash Flow and Net Debt 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 Adjusted EBITDA, Free Cash Flow and Net Debt differently from the way we do, which may limit their usefulness as comparative measures. Adjusted EBITDA, Free Cash Flow and Net Debt 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. Users of this financial information should consider the types of events and transactions that are excluded from these measures. See reconciliation of the non-GAAP financial information presented in this press release to the most directly comparable financial information presented in accordance with GAAP. We have not provided reconciliations of forward-looking non-GAAP financial measures to comparable GAAP measures due to the challenges and impracticability with estimating some of the items without unreasonable effort, which amounts could be significant.

Forward-Looking Statements

This press release contains forward-looking statements that involve risks, uncertainties and assumptions that could cause our results to differ materially from those expressed or implied by such forward-looking statements. All statements, other than statements of historical fact, are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995, including, without limitation, any statements regarding: our plans, strategies and objectives for future operations; any projections of financial items including projections as to guidance and other outlook information; future operations expenditures; our ability to enter into, renew and/or perform commercial contracts; the spot market; our current work continuing; visibility and future utilization; our protocols and plans; future economic or political conditions; energy transition or energy security; our spending and cost management efforts and our ability to manage changes; oil price volatility and its effects and results; our ability to identify, effect and integrate mergers, acquisitions and joint ventures or other transactions; developments; any financing transactions or arrangements or our ability to enter into such transactions or arrangements; our sustainability initiatives; our share repurchase program or execution; any statements of expectation or belief; and any statements of assumptions underlying any of the foregoing. Forward-looking statements are subject to a number of known and unknown risks, uncertainties and other factors that could cause results to differ materially from those in the forward-looking statements, including but not limited to market conditions and the demand for our services; volatility of oil and natural gas prices; complexities of global political and economic developments, including tariffs; results from mergers, acquisitions, joint ventures, divestitures or similar transactions; results from acquired properties; our ability to secure and realize backlog; the performance of contracts by customers, suppliers and other counterparties; actions by governmental and regulatory authorities; operating hazards and delays, which include delays in delivery, chartering or customer acceptance of assets or terms of their acceptance; the effectiveness of our sustainability initiatives and disclosures; human capital management issues; geologic risks; and other risks described from time to time in our filings with the Securities and Exchange Commission (“SEC”), including our most recently filed Annual Report on Form 10-K, which are available free of charge on the SEC’s website at www.sec.gov. We assume no obligation and do not intend to update these forward-looking statements, which speak only as of their respective dates, except as required by law.

HELIX ENERGY SOLUTIONS GROUP, INC.

Comparative Condensed Consolidated Statements of Operations

Three Months Ended Mar. 31,

(in thousands, except per share data)

2026

2025

(unaudited)

Net revenues

287,946

278,064

Cost of sales

279,118

250,526

Gross profit

8,828

27,538

Selling, general and administrative expenses

(22,143)

(19,366)

Income (loss) from operations

(13,315)

8,172

Net interest expense

(5,229)

(5,706)

Other income (expense), net

298

(357)

Royalty income and other

1,688

1,416

Income (loss) before income taxes

(16,558)

3,525

Income tax provision (benefit)

(3,152)

453

Net income (loss)

(13,406)

3,072

Earnings (loss) per share of common stock:

Basic

(0.09)

0.02

Diluted

(0.09)

0.02

Weighted average common shares outstanding:

Basic

147,163

151,039

Diluted

147,163

152,174

Comparative Condensed Consolidated Balance Sheets

Mar. 31, 2026

Dec. 31, 2025

(in thousands)

(unaudited)

ASSETS

Current Assets:

Cash and cash equivalents

501,272

445,196

Accounts receivable, net

230,112

303,939

Other current assets

87,907

75,857

Total Current Assets

819,291

824,992

Property and equipment, net

1,320,078

1,362,494

Operating lease right-of-use assets

302,926

302,649

Deferred recertification and dry dock costs, net

73,493

74,351

Other assets, net

52,301

51,418

Total Assets

2,568,089

2,615,904

LIABILITIES AND SHAREHOLDERS' EQUITY

Current Liabilities:

Accounts payable

138,412

134,287

Accrued liabilities

69,137

94,951

Current maturities of long-term debt

9,394

9,644

Current operating lease liabilities

64,112

60,796

Total Current Liabilities

281,055

299,678

Long-term debt

294,367

298,351

Operating lease liabilities

257,889

260,959

Deferred tax liabilities

104,972

105,571

Other non-current liabilities

72,950

71,433

Shareholders' equity

1,556,856

1,579,912

Total Liabilities and Equity

2,568,089

2,615,904

HELIX ENERGY SOLUTIONS GROUP, INC.

Comparative Condensed Consolidated Statements of Cash Flows

Three Months Ended

(in thousands)

3/31/2026

3/31/2025

(unaudited)

Cash flows from operating activities:

Net income (loss)

(13,406)

3,072

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

Depreciation and amortization

43,864

42,482

Deferred certification and dry dock costs

(8,870)

(17,855)

Other non-cash charges

824

1,238

Changes in operating assets and liabilities

39,374

(12,495)

Net cash provided by operating activities

61,786

16,442

Cash flows from investing activities:

Capital expenditures

(2,811)

(4,488)

Net cash used in investing activities

(2,811)

(4,488)

Cash flows from financing activities:

Repayments of long-term debt

(4,763)

(4,537)

Other financing activities

420

(6,538)

Net cash used in financing activities

(4,343)

(11,075)

Effect of exchange rate changes on cash and cash equivalents

1,444

1,078

Net increase in cash and cash equivalents

56,076

1,957

Cash and cash equivalents:

Balance, beginning of year

445,196

368,030

Balance, end of period

501,272

369,987

Reconciliation of Non-GAAP Measures

Three Months Ended

(in thousands, unaudited)

3/31/2026

3/31/2025

12/31/2025

Reconciliation from Net Income (Loss) to Adjusted EBITDA:

Net income (loss)

(13,406)

3,072

8,270

Adjustments:

Income tax provision (benefit)

(3,152)

453

(1,972)

Net interest expense

5,229

5,706

5,580

Depreciation and amortization

43,864

42,482

43,850

Other (income) expense, net

(298)

357

487

Long-lived asset impairment

—

18,064

General provision for (release of) current expected credit losses

(85)

(408)

Adjusted EBITDA

32,262

51,985

73,871

Free Cash Flow:

Cash flows from operating activities

61,786

16,442

113,163

Less: Capital expenditures, net of proceeds from asset sales

(2,811)

(4,488)

(5,696)

Free Cash Flow

58,975

11,954

107,467

Net Debt:

Long-term debt including current maturities

303,761

311,109

307,995

Less: Cash and cash equivalents

(501,272)

(369,987)

(445,196)

Net Debt

(197,511)

(58,878)

(137,201)

EX-99.2

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April 23, 2026

First Quarter

2026

Earnings Conference Call

EXHIBIT 99.2

This presentation contains forward-looking statements that involve risks, uncertainties and assumptions that could

cause our results to differ materially from those expressed or implied by such forward-looking statements. All

statements, other than statements of historical fact, are "forward-looking statements" within the meaning of the Private

Securities Litigation Reform Act of 1995, including, without limitation, any statements regarding: our plans, strategies

and objectives for future operations; any projections of financial items including projections as to guidance and other

outlook information; future operations expenditures; our ability to enter into, renew and/or perform commercial

contracts; the spot market; our current work continuing; visibility and future utilization; our protocols and plans; future

economic or political conditions; energy transition or energy security; our spending and cost management efforts and

our ability to manage changes; oil price volatility and its effects and results; our ability to identify, effect and integrate

mergers, acquisitions, joint ventures, divestitures or other transactions; developments; any financing transactions or

arrangements or our ability to enter into such transactions or arrangements; our sustainability initiatives; our share

repurchase program or execution; any statements of expectation or belief; and any statements of assumptions

underlying any of the foregoing. Forward-looking statements are subject to a number of known and unknown risks,

uncertainties and other factors that could cause results to differ materially from those in the forward-looking

statements, including but not limited to market conditions and the demand for our services; volatility of oil and natural

gas prices; complexities of global political and economic developments; results from mergers, acquisitions, joint

ventures or similar transactions; results from acquired properties; our ability to secure and realize backlog; the

performance of contracts by customers, suppliers and other counterparties; actions by governmental and regulatory

authorities; operating hazards and delays, which include delays in delivery, chartering or customer acceptance of

assets or terms of their acceptance; the effectiveness of our sustainability initiatives and disclosures; human capital

management issues; geologic risks; and other risks described from time to time in our filings with the Securities and

Exchange Commission ("SEC"), including our most recently filed Annual Report on Form 10-K, which are available free

of charge on the SEC's website at www.sec.gov. We assume no obligation and do not intend to update these forward-looking statements, which speak only as of their respective dates, except as required by law.

Forward-Looking Statements

• Executive Summary (pg. 4)

• Operational Highlights (pg. 7)

• Key Financial Metrics and Outlook (pg. 12)

• Non-GAAP Reconciliations (pg. 18)

• Questions and Answers

Agenda

Executive

Summary

Summary of Results

($ in millions, except per share amounts, unaudited) Three Months Ended

3/31/26 3/31/25 12/31/25

Revenues 288 $ 278 $ 334 $

Gross profit 9 $ 28 $ 51 $

3% 10% 15%

Net (loss) income1

$ 3 (13) $ 8 $

Basic (loss) earnings per share (0.09) $ 0.02 $ 0.06 $

Diluted (loss) earnings per share $ 0.02 (0.09) $ 0.06 $

Adjusted EBITDA2

Business segments 44 $ 61 $ 87 $

Corporate, eliminations and other (12) (9) (13) Adjusted EBITDA2

$ 52 32 $ 74 $

Cash and cash equivalents 501 $ 370 $ 445 $

Net Debt2

$ (59) (198) $ (137) $

Cash flows from operating activities 62 $ 16 $ 113 $

Free Cash Flow2

$ 12 59 $ 107 $ 1 Net income during the fourth quarter 2025 included a non-cash impairment loss of $18 million related to our Thunder Hawk oil and gas properties 2 Adjusted EBITDA, Net Debt and Free Cash Flow are non-GAAP financial measures; see non-GAAP reconciliations below

Amounts may not add due to rounding

Financial Results

• Net loss of $13 million, $(0.09) per diluted share

• Adjusted EBITDA1

of $32 million

• Operating cash flows of $62 million

• Free Cash Flow1

of $59 million

Financial Condition

• Cash and cash equivalents of $501 million

• Liquidity2

of $612 million

• Long-term debt3

of $304 million

• Negative Net Debt1

of $198 million

Operations

• Return to operations and good utilization on the Seawell in the North Sea

• Successful workover and recommencement of production of our Thunder

Hawk field

First Quarter 2026 Highlights

1 Adjusted EBITDA, Free Cash Flow and Net Debt are non-GAAP financial measures; see non-GAAP reconciliations below

2 Revenue percentages net of intercompany eliminations

Production

Maximization

28%

Decommissioning

56%

Renewables

13%

Other

Revenue By Market Strategy2

Quarter Ended March 31, 2026

Adjusted Amounts may not add due to rounding

Operational

Highlights

Well Intervention

• Fleet utilization 82%

• 91% in the Gulf of America

• 47% in the North Sea

• 100% in Brazil (including the Sea Helix 1, Siem Helix 2 and Q7000)

• 15K IRS idle; 10K IRSs idle; ROAM idle

Production Facilities • Helix Producer I operated at full rates

• Droshky field produced throughout Q1; Thunder Hawk field shut in prior to workover

completed end Q1

Robotics

• 381 vessel days (79% utilization)

• 122 integrated vessel trenching days

• 2,079 work class ROV days

• 56% overall ROV and trencher utilization

Shallow Water Abandonment

• 41% liftboat, offshore supply vessel (OSV) and crewboat combined utilization

• 15% diving support vessel (DSV) utilization

• Epic Hedron heavy lift barge idle

• 369 days, or 16%, combined utilization on plug and abandonment (P&A) and coiled

tubing (CT) systems

Segment Results

($ in millions, unaudited) Three Months Ended

3/31/26 3/31/25 12/31/25

Revenues

Well Intervention 209 $ 198 $ 181 $

Robotics 62 51 87 Shallow Water Abandonment 21 17 58

Production Facilities 19 20 17

Intercompany eliminations (24) (8) (9) Total 288 $ 278 $ 334 $

Gross profit (loss) %

Well Intervention 15 $ 7% $ 24 12% $ 16 9%

Robotics 11 17% 8 16% 22 25%

Shallow Water Abandonment (9) (42%) (12) (69%) 10 18%

Production Facilities (7) (40%) 7 38% 3 18%

Eliminations and other (1) (1) (1) Total 9 $ 3% $ 28 10% $ 51 15%

Utilization

Well Intervention vessels 82% 67% 72%

Robotics vessels 79% 67% 91%

Robotics assets (ROVs and trenchers) 56% 51% 58%

Shallow Water Abandonment vessels 35% 30% 54%

Shallow Water Abandonment systems 16% 11% 26%

Amounts may not add due to rounding

First Quarter Utilization

• Q5000 (Gulf of America) – 82% utilized in Q1; completed a single-well

production enhancement project for BP, followed by a workover of a Thunder

Hawk well on behalf of our Production Facilities segment; vessel then

underwent annual regulatory inspection, completed a single well production

enhancement scope for Talos, and commenced multi-well campaign for Shell • Q4000 (Gulf of America) – 100% utilized in Q1; completed construction

campaign and decommissioning scopes for Murphy and commenced multi-well decommissioning and production enhancement for Oxy

• Well Enhancer (North Sea) – 34% utilized in Q1; returned to work in March

and performed decommissioning operations

• Seawell (North Sea) – 60% utilized in Q1; returned to work in February

following 2025 warm stacking and performed decommissioning operations

• Q7000 (Brazil) – 100% utilized in Q1; performed decommissioning

operations on 20 wells for Shell Brazil, including open water tubing recovery

scopes on 11 wells and final abandonment of 9 wells, and one tree recovery • Sea Helix 1 (Brazil) – 100% utilized in Q1; completed decommissioning

scopes on three wells and a production enhancement scope on one well for

Petrobras

• Siem Helix 2 (Brazil) – 99% utilized in Q1; completed decommissioning

scopes on three wells for Petrobras • 15K IRS – idle during Q1

• 10K IRSs – idle during Q1 • ROAM – idle during Q1

Well Intervention

1 Gulf of America utilization includes Q4000 utilization offshore Nigeria between Q4 2024 and Q2 2025 on a six-month contract 2 North Sea utilization includes Seawell utilization in the western Mediterranean during Q1 and Q2 2024 3 Q7000 utilization includes utilization in Australia in 2024 and Brazil in 2025 and 2026

• Grand Canyon II (Asia Pacific) – 81 days (90%) utilized in Q1; performed

oil and gas ROV support projects offshore Malaysia and Indonesia; ended

Q1 commencing transit to North Sea for long-term trenching contract • Grand Canyon III (North Sea) – 61 days (79%) utilized in Q1; performed

renewables trenching and other ROV support and site clearance work for

one customer; spent most of February in scheduled regulatory drydock

• Shelia Bordelon (Gulf of America/ US East Coast) – 67 days (75%) utilized

in Q1; performed oil and gas ROV support work for two customers in Gulf of

America and renewables work for another customer on US East Coast • North Sea Enabler (North Sea) – 90 days (100%) utilized in Q1;

performed renewables trenching for two customers • Patriot (North Sea/Baltic Sea) – 20 days (26%) utilized in Q1; delivered into

fleet mid-January and commenced its first project in March in the Baltic Sea

performing both UXO ID and boulder relocation scopes • Trym (North Sea) – 61 days (100%) utilized in Q1; performed renewables

UXO ID operations for one customer; off hire for approximately 29 days for

repairs

• Trenching – 122 integrated vessel trenching days on renewables and oil

and gas trenching projects on Grand Canyon III and North Sea Enabler; 90

days stand-alone trenching with the T1400-2 on third-party vessel; T1400-1

idle • Site Clearance – 110 days utilization on three IROV boulder grabs on the

Trym, Patriot and Grand Canyon III

Robotics

Integrated vessel trenching days represents trenching activities utilizing Helix trenchers on Helix-chartered vessels and excludes stand-alone trenching operations on third-party vessels 2

Integrated vessel ROV days represents work-class ROV and IROV site clearance activities on Helix-chartered vessels

Lower expected seasonal utilization on Gulf of America shelf operations; several vessels remain temporarily stacked as a cost reduction measure

based on current market conditions; stacked vessels are included in utilization metrics above

Shallow Water Abandonment

Offshore

• Liftboats – nine liftboats with 47% combined

utilization; two liftboats stacked

• OSVs – six OSVs and one crew boat with 34%

combined utilization; three OSVs stacked

Energy Services

• P&A Systems – 334 days utilization, or 19%, on 20

P&A systems

• CT Systems – 35 days utilization, or 6%, on six CT

systems

Diving & Heavy Lift • Epic Hedron – idle during Q1

• DSVs – three DSVs with combined utilization of 15%

Key Financial

Metrics and

Outlook

Total funded debt† of $310 million at 3/31/26

• $300 million Senior Notes due 2029 – 9.75%

• $10 million MARAD Debt – 4.93%

• Semi-annual amortization payments through maturity in Q1 2027

Debt Instrument Profile

† Funded debt represents the principal amount of our long-term debt before

subtracting $6 million of remaining unamortized debt discount and issuance costs

$5 $5

$300

2026 2027 2028 2029

Principal Payment Schedule at 3/31/26

($ in millions)

MARAD 2029 Senior Notes

$332 $368

$445

$501

($362) ($315) ($308) ($304)

$431 $430

$554

$612

$(30)

$53

$137

$198

Cash Long-term debt Liquidity Net Debt

12/31/23 12/31/24 12/31/25 3/31/26

Debt and Liquidity Profile at 3/31/26

($ in millions)

1 Long-term debt net of debt issuance costs

Liquidity is calculated as the sum of cash and cash equivalents and available capacity

under Helix’s ABL facility but excludes cash pledged to the ABL facility

3 Net Debt is a non-GAAP financial measure; see non-GAAP reconciliations below

1 2 3 Amounts may not add due to rounding

Minimal maturities until 2029; Significant net cash position and strong liquidity at 3/31/26

Our 2026 outlook will be affected by, among other things, the

utilization and rates in our spot and call-off operations and the extent

of winter seasonal activity and the following expected key drivers:

Well Intervention • Q4000 – second half 2026 utilization

• Q7000 – second half 2026 utilization

• Brazil – overall operating efficiency and Sea Helix 1 docking

• North Sea – second half 2026 spot market utilization

Robotics

• Seasonal vessel utilization in the North Sea and Asia Pacific

Shallow Water Abandonment

• Strength of contracting for oil and gas properties in bankruptcies

reverting to former owners

• Seasonal utilization and level of competition on the Gulf of America

shelf

Free Cash Flow

• Forecasted variability due to the seasonality of our operations and the

timing of collections on our receivables

2026 Forecast

($ in millions) 2026 2025

Outlook Actual

Revenues $ 1,200 - 1,400 1,291 $

Adjusted EBITDA1

230 - 290 272 Capital Additions2

70 - 80 70 Free Cash Flow1

100 - 160 120 Revenue Split:

Well Intervention $ 695 - 830 729 $

Robotics 305 - 335 323 Shallow Water Abandonment 160 - 190 200

Production Facilities 90 - 95 73 Eliminations (50) (34)

Total Revenue $ 1,200 - 1,400 1,291 $

1 Adjusted EBITDA and Free Cash Flow are non-GAAP financial measures; see non-GAAP reconciliations below

2 Capital Additions include regulatory certification costs for our vessels and systems as well as other capital expenditures

Key Financial Metrics Key Forecast Drivers

Amounts may not add due to rounding

• Seasonal activities typically generate stronger

performance during Q2 and Q3 and a decline

in activity during Q1 and Q4:

• Seasonal peaks generally in Q3 and troughs in

• Business units most impacted by seasonality

include:

• Well Intervention and Robotics in the North

Sea

• Shallow Water Abandonment

• Quarterly activity also influenced by the timing

of regulatory dockings and long-term transits

and mobilizations

Historical Quarterly Revenue & Earnings ($ in millions)

1 Adjusted EBITDA is a non-GAAP financial measure; see non-GAAP reconciliations below

$296

$365

$342 $355

$278

$302

$377

$334

$288

$(26)

$32

$30 $20 $3

$(3)

$22 $8 $(13)

$47

$97 $88 $72 $52 $42

$104

$74

$32

Q1 24 Q2 24 Q3 24 Q4 24 Q1 25 Q2 25 Q3 25 Q4 25 Q1 26

Revenue Net Income Adjusted EBITDA¹

Well Intervention

• Q5000 (Gulf of America) – completed workover of Helix’s Thunder Hawk field in

March; expected to have good utilization with contracted work and identified

opportunities for remainder of 2026 • Q4000 (Gulf of America) – contracted into Q2; identified opportunities for the

remainder of 2026 with schedule gaps expected between contracts

• Well Enhancer (North Sea) – contracted decommissioning and production

enhancement through Q3 followed by expected North Sea seasonal slowdown in

• Seawell (North Sea) – contracted work well into Q4 followed by expected

seasonal slowdown for remainder of year • Q7000 (Brazil) – contracted with Shell Brazil through end of April; identified

opportunities in Brazil and West Africa • Sea Helix 1 (Brazil) – Contracted with Petrobras into Q4 2028

• Siem Helix 2 (Brazil) – Contracted with Petrobras into Q1 2028

• IRS rental units (Global) – 15K IRS and 10K IRS rentals available and being

marketed globally with identified opportunities in the Gulf of America

Shallow Water Abandonment

Expect seasonal activity, with higher utilization during Q2 and Q3 and lower

utilization in Q1 and Q4 • Liftboats – expect seasonal utilization on up to seven liftboats during 2026

• OSVs – expect seasonal utilization on up to five OSVs during 2026

• P&A Systems – expect seasonal utilization on up to eight P&A systems during

2026

• CT Systems – expect seasonal utilization on up to two CT systems during 2026

• DSVs – expect seasonal utilization on all three diving vessels during 2026

• Epic Hedron – vessel available in Q2 and expected good seasonal utilization

during 2026

Robotics

• Grand Canyon II (Asia Pacific/North Sea) – transiting to North Sea for long-term

trenching contract expected to commence in 2027 • Grand Canyon III (North Sea) – expected to be nearly fully utilized in 2026 on

trenching projects • Shelia Bordelon (U.S.) – performing renewables operations on US East Coast

expected through April 2026 with identified subsequent opportunities on US East

Coast and in the Gulf of America; vessel charter expires end of Q2 2026 if not

extended • North Sea Enabler (North Sea) – under flexible charter during first half 2026 with

two-year charter extension commencing July; expected to be nearly fully utilized

in 2026 on trenching projects for both renewables and oil and gas customers

• Trym (North Sea) – expected to perform UXO identification and other

renewables site preparation and site clearance work with high utilization

expected in 2026

• Patriot (North Sea/Baltic Sea) – expected to continue its Baltic Sea UXO ID and

Boulder removal project into Q4 2026

• Trenchers (Global) – six trenchers with good utilization expected on four

integrated vessel trencher spreads in the North Sea and one trencher working on

third-party vessel in the Mediterranean

• ROVs (Global) – expect stronger ROV utilization in 2026 over 2025

Production Facilities

• Helix Producer I – under contract throughout 2026 • Thunder Hawk – wells recommenced production in April with production

expected through remainder of 2026 • Droshky – ongoing production expected to decline throughout 2026

2026 Segments Outlook

2026 Capital additions1

are forecasted at approximately $70 – $80 million:

• Capital additions during Q1 included approximately $10 million for regulatory certifications costs for our vessels and

systems, which are reported in operating cash flows, and approximately $2 million for capital expenditures

• Capital additions during the remainder of 2026 are expected to be:

• Approximately $30 – $35 million for regulatory certification costs for our vessels and systems, reported in operating

cash flows

• Approximately $28 – $33 million for capital expenditures, reported in investing cash flows

Free Cash Flow2

• Free Cash Flow outlook includes approximately $70 – $80 million of capital spending, $30 million of gross cash

interest expense, and cash income taxes expected between $20 – $30 million

• Working capital expected to be impacted by seasonality and timing of collections from customers

Balance Sheet

• No significant debt maturities until 2029

Capital Additions, Cash Flow and Balance Sheet

1 Capital additions represents accrued capital additions; total cash capital spending was approximately $9 million for regulatory certifications cost and $3 million

for capital expenditures during Q1

2 Free Cash Flow is a non-GAAP financial measure; see non-GAAP reconciliations below

Non-GAAP

Reconciliations

Non-GAAP Reconciliations

Year Ended

($ in thousands, unaudited) 3/31/24 6/30/24 9/30/24 12/31/24 3/31/25 6/30/25 9/30/25 12/31/25 3/31/26 12/31/25

Reconciliation from Net Income (Loss) to

Adjusted EBITDA:

Net income (loss) (26,287) $ 32,289 $ 29,514 $ 20,121 $ 3,072 $ (2,598) $ 22,083 $ 8,270 $ (13,406) $ $30,827

Adjustments:

Income tax provision (benefit) (1,698) 14,725 9,520 3,880 453 (5,997) 19,169 (1,972) (3,152) 11,653 Net interest expense 5,477 5,891 5,689 5,572 5,706 5,875 5,616 5,580 5,229 22,777 Depreciation and amortization 46,353 43,471 42,904 40,564 42,482 45,389 55,661 43,850 43,864 187,382 Other (income) expense, net 2,216 382 49 1,275 357 (437) 983 487 (298) 1,390 (Gain) loss on disposition of assets 150 - (100) 429 - - - - - - Long-lived asset impairment - - - - - - - 18,064 - 18,064 Losses related to convertible senior notes 20,922 - - - - - - - - - General provision for (release of) current expected

credit losses (143) 137 45 (200) (85) 198 159 (408) 25 (136) Adjusted EBITDA $ 96,895 46,990 $ 87,621 $ 71,641 $ 51,985 $ 42,430 $ 103,671 $ 73,871 $ 32,262 $ 271,957 $

Free Cash Flow:

Cash flows from operating activities 64,484 $ (12,164) $ 55,731 $ 77,977 $ 16,442 $ (17,133) $ 24,277 $ 113,163 $ 61,786 $ 136,749 $

Less: Capital expenditures, net of proceeds from

asset sales and insurance recoveries (3,242) (3,989) (3,086) (12,523) (4,488) (4,470) (1,688) (5,696) (2,811) (16,342) Free Cash Flow $ (16,153) 61,242 $ 52,645 $ 65,454 $ 11,954 $ (21,603) $ 22,589 $ 107,467 $ 58,975 $ 120,407 $

Net Debt:

Long-term debt including current maturities of long-term debt 318,164 $ 318,629 $ 314,673 $ 315,157 $ 311,109 $ 311,612 $ 307,472 $ 307,995 $ 303,761 $ 307,995 $

Less: Cash and cash equivalents and restricted cash (323,849) (275,066) (324,120) (368,030) (369,987) (319,743) (338,033) (445,196) (501,272) (445,196) Net Debt $ 43,563 (5,685) $ (9,447) $ (52,873) $ (58,878) $ (8,131) $ (30,561) $ (137,201) $ (197,511) $ (137,201) $

Three Months Ended

Non-GAAP Financial Measures

We define Adjusted EBITDA as earnings before income taxes, net interest expense, depreciation and amortization expense, net

other income or expense, gains or losses on disposition of assets, long-lived asset impairment losses, acquisition and

integration costs, gains or losses related to convertible senior notes, the change in fair value of contingent consideration and the

general provision for (release of) current expected credit losses, if any. We define Free Cash Flow as cash flows from operating

activities less capital expenditures, net of proceeds from asset sales and insurance recoveries (related to property and

equipment), if any. Net debt is calculated as long-term debt including current maturities of long-term debt less cash and cash

equivalents and restricted cash.

We use Adjusted EBITDA, Free Cash Flow and Net Debt 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 Adjusted EBITDA, Free Cash Flow and Net Debt 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 Adjusted EBITDA, Free Cash Flow and Net Debt differently from the way we do, which may limit their

usefulness as comparative measures. Adjusted EBITDA, Free Cash Flow and Net Debt 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. Users of this financial information should consider the types

of events and transactions that are excluded from these measures. See reconciliation of the non-GAAP financial information

presented in this press release to the most directly comparable financial information presented in accordance with GAAP. We

have not provided reconciliations of forward-looking non-GAAP financial measures to comparable GAAP measures due to the

challenges and impracticability with estimating some of the items without unreasonable effort, which amounts could be

significant.

Non-GAAP Reconciliations

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v3.26.1

Document and Entity Information

Apr. 22, 2026

Document and Entity Information [Abstract]

Document Type

8-K

Document Period End Date

Apr. 22, 2026

Entity File Number

001-32936

Entity Registrant Name

HELIX ENERGY SOLUTIONS GROUP, INC.

Entity Incorporation, State or Country Code

Entity Tax Identification Number

95-3409686

Entity Address, Address Line One

3505 West Sam Houston Parkway North

Entity Address, Adress Line Two

Suite 400

Entity Address, City or Town

Houston

Entity Address, State or Province

Entity Address, Postal Zip Code

77043

City Area Code

281

Local Phone Number

618-0400

Written Communications

false

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false

Pre-commencement Tender Offer

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Pre-commencement Issuer Tender Offer

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Title of 12(b) Security

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Trading Symbol

HLX

Security Exchange Name

NYSE

Entity Emerging Growth Company

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No definition available.

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For the EDGAR submission types of Form 8-K: the date of the report, the date of the earliest event reported; for the EDGAR submission types of Form N-1A: the filing date; for all other submission types: the end of the reporting or transition period. The format of the date is YYYY-MM-DD.

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No definition available.

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- Definition

The type of document being provided (such as 10-K, 10-Q, 485BPOS, etc). The document type is limited to the same value as the supporting SEC submission type, or the word 'Other'.

+ References

No definition available.

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- Definition

Address Line 1 such as Attn, Building Name, Street Name

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No definition available.

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- Definition

Address Line 2 such as Street or Suite number

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No definition available.

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- Definition

Name of the City or Town

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No definition available.

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- Definition

Code for the postal or zip code

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No definition available.

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- Definition

Name of the state or province.

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No definition available.

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- Definition

A unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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- Definition

Indicate if registrant meets the emerging growth company criteria.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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- Definition

Commission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.

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No definition available.

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- Definition

Two-character EDGAR code representing the state or country of incorporation.

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No definition available.

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- Definition

The exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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- Definition

The Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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- Definition

Local phone number for entity.

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No definition available.

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- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 13e

-Subsection 4c

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Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14d

-Subsection 2b

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- Definition

Title of a 12(b) registered security.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b

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- Definition

Name of the Exchange on which a security is registered.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection d1-1

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Name:

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- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act.

+ References

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

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14a

-Subsection 12

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- Definition

Trading symbol of an instrument as listed on an exchange.

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No definition available.

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- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act.

+ References

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

-Publisher SEC

-Name Securities Act

-Number 230

-Section 425

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