8-K

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): February 21, 2023 (February 20, 2023)

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 February 20, 2023, Helix Energy Solutions Group, Inc. (“Helix”) issued a press release reporting its financial results for the fourth quarter and full year 2022. The press release is furnished herewith as Exhibit 99.1 and incorporated herein by reference.

Item 7.01 Regulation FD Disclosure.

On February 20, 2023, Helix issued a press release reporting its financial results for the fourth quarter and full year 2022. In addition, on February 21, 2023, 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 Fourth Quarter 2022 Conference Call Presentation issued by Helix. The presentation materials are also available on the “For the Investor” page 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 8.01 Other Events.

On February 20, 2023, Helix issued a press release announcing that its Board of Directors authorized the repurchase of up to $200 million of Helix’s issued and outstanding shares of common stock. Attached hereto as Exhibit 99.3, and incorporated herein by reference, is the press release.

Item 9.01 Financial Statements and Exhibits.

(d)           Exhibits.

Exhibit Number	Description
99.1	Press Release of Helix Energy Solutions Group, Inc. dated February 20, 2023 reporting financial results for the fourth quarter and full year 2022.
99.2	Fourth Quarter 2022 Conference Call Presentation.
99.3	Press Release of Helix Energy Solutions Group, Inc. dated February 20, 2023 announcing Share Repurchase Program.
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: February 21, 2023
	HELIX ENERGY SOLUTIONS GROUP, INC.
	By:	/s/ Erik Staffeldt
		Erik Staffeldt
		Executive Vice President and Chief Financial Officer

EX-99.1

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								23-003
Date: February 20, 2023		Contact:	Erik Staffeldt
			Executive Vice President & CFO

Helix Reports Fourth Quarter and Full Year 2022 Results

HOUSTON, TX – Helix Energy Solutions Group, Inc. (“Helix”) (NYSE: HLX) reported net income¹ of $2.7 million, or $0.02 per diluted share, for the fourth quarter 2022 compared to net losses of $18.8 million, or $(0.12) per diluted share, for the third quarter 2022 and $25.9 million, or $(0.17) per diluted share, for the fourth quarter 2021.  Helix reported adjusted EBITDA² of $49.2 million for the fourth quarter 2022 compared to $52.6 million for the third quarter 2022 and $8.8 million for the fourth quarter 2021.

For the full year 2022, Helix reported a net loss of $87.8 million, or $(0.58) per diluted share, compared to a net loss of $61.5 million, or $(0.41) per diluted share, for the full year 2021.  Adjusted EBITDA for the full year 2022 was $121.0 million compared to $96.3 million for the full year 2021.  The table below summarizes our results of operations:

Summary of Results

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

	Three Months Ended									Year Ended
	12/31/2022			12/31/2021			9/30/2022			12/31/2022			12/31/2021
Revenues	$	287,816		$	168,656		$	272,547		$	873,100		$	674,728
Gross Profit (Loss)	$	31,364		$	(5,361)		$	39,215		$	50,616		$	15,393
		11	%		(3)	%		14	%		6	%		2	%
Net Income (Loss)1	$	2,709		$	(25,908)		$	(18,763)		$	(87,784)		$	(61,538)
Diluted Earnings (Loss) Per Share	$	0.02		$	(0.17)		$	(0.12)		$	(0.58)		$	(0.41)
Adjusted EBITDA2	$	49,169		$	8,764		$	52,568		$	121,022		$	96,276
Cash and Cash Equivalents3	$	186,604		$	253,515		$	162,268		$	186,604		$	253,515
Net Debt 2	$	74,964		$	(22,117)		$	98,807		$	74,964		$	(22,117)
Cash Flows from Operating Activities	$	49,712		$	18,865		$	24,650		$	51,108		$	140,117
Free Cash Flow2	$	21,198		$	17,929		$	21,847		$	17,604		$	131,846

Owen Kratz, President and Chief Executive Officer of Helix, stated, “Our fourth quarter 2022 results maintained strong performance sequentially in what is normally a seasonally slower period for Helix.  Our fourth quarter results were aided by a healthy oil and gas market, seasonally adjusted but strong Robotics operations, and ongoing contribution from our Alliance acquisition.  We acquired Alliance mid-year, which has added to our capabilities and enhanced our position as a full-field decommissioning provider.  Our Siem Helix vessels have both transitioned to long-term campaigns in Brazil.  The Q7000 has completed a successful campaign in Nigeria and is transitioning to Asia Pacific for contracted decommissioning work after which it is contracted for decommissioning work in Brazil in 2024.  We have acquired targeted niche equipment during the year including a boulder grab, three subsea trenchers and our interest in two deepwater intervention riser systems.  These acquisitions further enhance our capabilities as an energy transition global service provider.  Our strategy and focus have positioned us well for this improved energy market, and we have already begun to see the rewards of our efforts.   We grew revenue and EBITDA in 2022, and our results for 2022 mark our fifth consecutive year of positive free cash flow.  We are expecting 2023 to continue the improvements seen in the second half of 2022.  With our strong performance and with the improved current market environment, we were excited to announce earlier today that our board has authorized a $200 million share repurchase program which we believe is an excellent opportunity to increase shareholder value.”

(

¹ Net income (loss) attributable to common shareholders

² Adjusted EBITDA, Free Cash Flow and Net Debt are non-GAAP measures; see reconciliations below

³ Excludes restricted cash of $2.5 million as of 12/31/22 and 9/30/22 and $73.6 million as of 12/31/21

Segment Information, Operational and Financial Highlights

($ in thousands, unaudited)

	Three Months Ended						Year Ended
	12/31/2022		12/31/2021		9/30/2022		12/31/2022		12/31/2021
Revenues:
Well Intervention	$	167,658	$	119,177	$	143,925	$	524,241	$	516,564
Robotics		48,538		40,865		56,182		191,921		137,295
Shallow Water Abandonment 1		57,409		—		67,401		124,810		—
Production Facilities		27,895		20,131		18,448		82,315		69,348
Intercompany Eliminations		(13,684)		(11,517)		(13,409)		(50,187)		(48,479)
Total	$	287,816	$	168,656	$	272,547	$	873,100	$	674,728
Income (Loss) from Operations:
Well Intervention	$	2,554	$	(21,063)	$	(1,304)	$	(53,056)	$	(35,882)
Robotics		7,127		3,505		11,708		29,981		5,762
Shallow Water Abandonment 1		5,864		—		16,320		22,184		—
Production Facilities		9,237		6,621		6,068		27,201		22,906
Change in Fair Value of Contingent Consideration		(13,390)		—		(2,664)		(16,054)		—
Corporate / Other / Eliminations		(16,520)		(15,923)		(17,902)		(55,111)		(41,473)
Total	$	(5,128)	$	(26,860)	$	12,226	$	(44,855)	$	(48,687)

¹Shallow Water Abandonment includes the results of Helix Alliance beginning July 1, 2022, the date of acquisition

Fourth Quarter Results

Segment Results

Well Intervention

Well Intervention revenues increased $23.7 million, or 16%,during the fourth quarter 2022 compared to the prior quarter.  Our fourth quarter 2022 revenues increased due primarily to higher vessel utilization in West Africa, the Gulf of Mexico and the North Sea and higher rates in Brazil, offset in part by revenue deferrals on the Q7000 and lower seasonal rates in the North Sea compared to the prior quarter.  Gulf of Mexico vessel utilization improved during the fourth quarter with fewer idle days.  North Sea revenues improved during the fourth quarter due to higher utilization with strong winter seasonal activity, offset in part by lower winter seasonal rates.  Utilization in West Africa increased during the fourth quarter due to the Q7000 undergoing scheduled maintenance during the prior quarter, although revenues were deferred beginning mid-December 2022 during the vessel’s paid transit and mobilization to its contracted work in Asia Pacific in 2023.  Overall Well Intervention vessel utilization increased to 97% during the fourth quarter 2022 compared to 87% during the prior quarter.  Well Intervention generated operating income of $2.6 million during the fourth quarter 2022 compared to a net loss from operations of $1.3 million during the prior quarter due to higher revenues.

Well Intervention revenues increased $48.5 million, or 41%, during the fourth quarter 2022 compared to the fourth quarter 2021.  The increase was due primarily to higher utilization and rates in the North Sea and the Gulf of Mexico and higher utilization in Brazil, offset in part by lower rates in Brazil on the Siem Helix 2 and revenue deferrals on the Q7000.  Revenues in the North Sea improved significantly year over year with strong winter seasonal activity and stronger rates during the fourth quarter 2022 compared to 8% utilization during the fourth quarter 2021.  North Sea revenue improvements during the fourth quarter 2022 were offset in part by a weaker British pound compared to the fourth quarter 2021.  Gulf of Mexico revenues also benefitted from an improved day rate environment and higher utilization year over year.  Revenues in Brazil increased during the fourth quarter 2022 primarily due to utilization on the Siem Helix 1, which had nominal utilization during the fourth quarter 2021, offset in part by lower rates on the Siem Helix 2 year over year.  Utilization on the Q7000 was strong in both the fourth quarters 2022 and 2021, although revenues were lower during the fourth quarter 2022 as transit and mobilization fees were deferred beginning mid-December with the vessel’s paid transit to its contracted work in Asia Pacific.  Overall Well Intervention vessel utilization increased to 97% during the fourth quarter 2022 from 56% during the fourth quarter 2021.  Well Intervention generated operating income of $2.6 million during the fourth quarter 2022 compared to a net loss from operations of $21.1 million during the fourth quarter 2021 due to higher revenues.

Robotics

Robotics revenues decreased $7.6 million, or 14%, during the fourth quarter 2022 compared to the prior quarter.  The decrease in revenues was due to seasonally lower vessel, ROV and trenching activities.  Chartered vessel days decreased to 332 days compared to 376 days with fewer spot vessel days, and vessel utilization decreased to 96% compared to 98%, during the fourth quarter 2022 compared the prior quarter.  Vessel days included 68 spot vessel days during the fourth quarter 2022 compared to 100 spot vessel days during the prior quarter.  ROV and trencher utilization decreased to 58% during the fourth quarter 2022 compared to 66% during the prior quarter.  Trenching days decreased to 160 days during the fourth quarter 2022, compared to 176 days during the prior quarter, on the Grand Canyon III and the Horizon Enabler.  Both quarters included utilization on the IROV boulder grab, which was acquired and deployed during the third quarter 2022, for seabed clearance operations on the U.S. east coast.  Robotics operating income decreased $4.6 million during the fourth quarter 2022 compared to the prior quarter due to lower revenues.

Robotics revenues increased $7.7 million, or 19%, during the fourth quarter 2022 compared to the fourth quarter 2021.  The increase in revenues was due to higher ROV and trenching activities, offset in part by fewer vessel days year over year.  ROV and trencher utilization increased to 58% during the fourth quarter 2022 from 38% during the fourth quarter 2021, and trenching days increased to 160 days during the fourth quarter 2022 compared to 90 days during the fourth quarter 2021.  Chartered vessel days decreased to 332 days compared to 419 days, and vessel utilization declined to 96% compared to 99%, during the fourth quarter 2022 compared to the fourth quarter 2021.  Vessel days decreased year over year primarily due to fewer spot vessel days during the fourth quarter 2022 performing site clearance work in the North Sea, which commenced during 2021 and completed during the third quarter 2022.  Robotics operating income increased $3.6 million during the fourth quarter 2022 compared to the fourth quarter 2021 due to higher revenues.

Shallow Water Abandonment

Shallow Water Abandonment revenues decreased $10.0 million, or 15%, during the fourth quarter 2022 compared to the previous quarter.  The decrease in revenues reflected the seasonal slowdown in the Gulf of Mexico shelf with a reduction in liftboat, OSV, DSV and heavy lift barge utilization, offset in part by higher plug and abandonment (P&A) and coiled tubing system utilization operating on customer platforms.  Liftboat, OSV and DSV utilization was 70% during the fourth quarter 2022 compared to 82% during the prior quarter.  The Epic Hedron heavy lift barge was idle during the fourth quarter 2022 compared to having 41% utilization during the prior quarter.  Marketable P&A and coiled tubing system days increased to 1,247, or 65% utilization based on 21 marketable systems, during the fourth quarter 2022 compared to 1,077, or 59% utilization based on 20 marketable systems, during the prior quarter.  Shallow Water Abandonment operating income decreased $10.5 million during the fourth quarter 2022 compared to the third quarter 2022 primarily due to lower revenues.

Production Facilities

Production Facilities revenues increased $9.4 million, or 51%, during the fourth quarter 2022 primarily due to higher oil and gas production from our Droshky wells and a full quarter of production from our Thunder Hawk wells following their acquisition on August 25, 2022, offset in part by lower oil and gas prices compared to the prior quarter.  Revenues also benefitted from retroactive rate adjustment on our production contract with the Helix Producer I.  Production Facilities operating income increased $3.2 million during the fourth quarter 2022 due to higher revenues, offset in part by higher production costs on increased production activity compared to the prior quarter.

Production Facilities revenues increased $7.8 million, or 39%, compared to the fourth quarter 2021 primarily due to higher oil and gas production with the contribution from our interest in the Thunder Hawk Field and improved rates on our Helix Producer I production contract.  Production Facilities operating income increased $2.6 million during the fourth quarter 2022 due to higher revenues, offset in part by higher production costs on increased production activity compared to the prior year.

Selling, General and Administrative and Other

Selling, General and Administrative

Selling, general and administrative expenses were $22.8 million, or 7.9% of revenue, during the fourth quarter 2022 compared to $23.6 million, or 8.6% of revenue, during the prior quarter.  The decrease during the fourth quarter was primarily due to lower incentive compensation costs and a reduction in general and administrative costs in our Shallow Water Abandonment segment compared to the prior quarter.

Acquisition and Integration Costs

Acquisition and integration costs were $0.3 million during the fourth quarter 2022, a decrease of $0.4 million compared to the prior quarter and included primarily legal and professional fees and financial and operational integration costs related to our acquisition of Alliance, which closed on July 1, 2022.

Change in Fair Value of Contingent Consideration

Change in fair value of contingent consideration was $13.4 million during the fourth quarter 2022 and reflects an increase in the fair value of the estimated earn-out payable in 2024 to the seller of the Alliance group of companies.

Other Income and Expenses

Other income, net was $14.3 million during the fourth quarter 2022 compared to an expense of $20.3 million during the prior quarter and includes predominantly unrealized non-cash foreign currency gains related to the approximate 8% strengthening of the British pound during the fourth quarter 2022 on U.S. dollar denominated intercompany debt in our U.K. entities.

Cash Flows

Operating cash flows were $49.7 million during the fourth quarter 2022 compared to $24.7 million during the prior quarter and $18.9 million during the fourth quarter 2021.  The improvement in operating cash flows quarter over quarter was primarily due to improvements in working capital and lower regulatory certification costs during the fourth quarter 2022 compared to the prior quarter.  The improvement in operating cash flows year over year was primarily due to improved operating results and improvements in working capital, offset in part by higher regulatory recertification costs for our vessels and systems during the fourth quarter 2022 compared to the fourth quarter 2021.  Regulatory recertification costs for our vessels and systems, which are included in operating cash flows, were $4.8 million during the fourth quarter 2022 compared to $10.7 million during the prior quarter and $2.5 million during the fourth quarter 2021.

Capital expenditures, which are included in investing cash flows, totaled $28.5 million during the fourth quarter 2022 compared to $2.8 million during the prior quarter and $0.9 million during the fourth quarter 2021.  Capital expenditures during the fourth quarter 2022 included our acquisition of three trenchers and our interest in two subsea intervention systems.

Free Cash Flow was $21.2 million during the fourth quarter 2022 compared to $21.8 million during the prior quarter and $17.9 million during the fourth quarter 2021.  The nominal decrease in Free Cash Flow quarter over quarter was due primarily to higher capital expenditures, offset almost entirely by higher operating cash flows during the fourth quarter 2022.  The increase in Free Cash Flow year over year was due primarily to higher operating cash flows, offset in part by higher capital expenditures during the fourth quarter 2022.  (Free Cash Flow is a non-GAAP measure.  See reconciliation below.)

Full Year Results

Segment Results

Well Intervention

Well Intervention revenues increased $7.7 million, or 1%, in 2022 compared to 2021.  The increase was primarily driven by higher vessel utilization and rates in the Gulf of Mexico and the North Sea.  The increase was offset in part by lower utilization on the Q7000 resulting from scheduled maintenance during 2022, lower rates on the Siem Helix 1 and Siem Helix 2 as they transitioned from their legacy contracts with Petrobras, and a weaker British pound during 2022 compared to 2021.  Overall Well Intervention vessel utilization increased to 80% during 2022 compared to 67% in 2021.  Well Intervention net loss from operations increased to $53.1 million during 2022 compared to $35.9 million in 2021.  The increase in the net loss was due to our mix of contracting year over year, with our lower rates in Brazil generating higher losses, offset by increased Gulf of Mexico and North Sea revenues generating lower incremental margins driven by an increase in integrated projects and reimbursable revenues during 2022.

Robotics

Robotics revenues increased $54.6 million, or 40%, in 2022 compared to 2021.  The increase was due to higher vessel, trenching and ROV activities in 2022.  Chartered vessel days increased to 1,401, which included 420 spot vessel days, in 2022 compared to 1,178, which included 477 spot vessel days, in 2021. Trenching days increased to 483 days in 2022 compared to 336 days in 2021.  Overall ROV and trencher utilization increased to 53% in 2022 compared to 36% in 2021.  Robotics operating income increased $24.2 million to $30.0 million in 2022 compared to $5.8 million in 2021.  The increase in operating income was due to higher revenues during 2022.

Shallow Water Abandonment

Shallow Water Abandonment generated revenues of $124.8 million and income from operations of $22.2 million, which reflected the operating results of Helix Alliance since its acquisition on July 1, 2022.  Liftboat, OSV and DSV utilization was 76%, Epic Hedron heavy lift barge utilization was 21% and utilization across marketable plug and abandonment (P&A) and coiled tubing systems was 2,324 days, or 62%, during the period from July 1, 2022 (date of acquisition) through December 31, 2022.

Production Facilities

Production Facilities revenues increased $13.0 million, or 19%, during 2022 compared to 2021. The increase was due to higher oil and gas prices and improved rates related to the Helix Fast Response System, offset in part by lower oil and gas production volumes in 2022.  Production Facilities operating income increased $4.3 million during 2022 due primarily to increases in revenues, offset in part by higher costs compared to 2021.

Selling, General and Administrative and Other

Selling, General and Administrative

Selling, general and administrative expenses were $76.8 million, or 8.8% of revenue, in 2022 compared to $63.4 million, or 9.4% of revenue, in 2021. The increase was primarily related to an increase in employee incentive and share-based compensation costs as well as increased general and administrative expenses related to Helix Alliance.

Net Interest Expense

Net interest expense decreased to $19.0 million in 2022 compared to $23.2 million in 2021.  The decrease was primarily associated with lower funded debt, which decreased by $42.9 million during 2022, and lower fees associated with our credit facility compared to 2021.

Change in Fair Value of Contingent Consideration

The change in fair value of contingent consideration relates to the change in the fair value of the estimated earn-out payable in 2024 to the seller of the Alliance group of companies.

Other Income and Expenses

Other expense, net was $23.3 million in 2022 compared to $1.5 million in 2021.  The change was primarily due higher foreign currency losses due to a weakening of the British pound in 2022 compared to 2021.

Cash Flows

Helix generated operating cash flows of $51.1 million in 2022 compared to $140.1 million in 2021.  The decrease in operating cash flows in 2022 was due to working capital outflows and higher regulatory certification costs in 2022 compared to improvements in working capital 2021, which included tax refunds of $18.9 million related to the CARES Act.  The decrease in operating cash flows was offset in part by higher operating income in 2022.  Regulatory certification costs, which are considered part of Helix’s capital spending program but are classified in operating cash flows, were $35.1 million in 2022 compared to $9.6 million in 2021.

Capital expenditures increased to $33.5 million in 2022 compared to $8.3 million in 2021 due primarily to the acquisition of three subsea trenchers and our interest in two subsea intervention systems during 2022.

Free Cash Flow was $17.6 million in 2022 compared to $131.8 million in 2021.  The decrease was due to lower operating cash flows and higher capital expenditures in 2022.  (Free Cash Flow is a non-GAAP measure.  See reconciliation below.)

Financial Condition and Liquidity

Cash and cash equivalents were $186.6 million at December 31, 2022, excluding $2.5 million of restricted cash.  Available capacity under our ABL facility at December 31, 2022 was $98.1 million, resulting in total liquidity of $284.7 million.  At December 31, 2022 we had $264.1 million of long-term debt and Net Debt of $75.0 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 fourth quarter and full year 2022 results (see the “For the Investor” page of Helix’s website, www.helixesg.com).  The teleconference, scheduled for Tuesday, February 21, 2023 at 9:00 a.m. Central Time, will be audio webcast live from the “For the Investor” page of Helix’s website.  Investors and other interested parties wishing to participate in the teleconference may join by dialing 1-877-207-9876 for participants in the United States and 1-212-231-2907 for international participants.  The passcode is “Staffeldt.”  A replay of the webcast will be available on the “For the Investor” page of Helix’s website by selecting the “Audio Archives” link beginning approximately two hours 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 full-field decommissioning operations.  Our services are centered on a three-legged business model well positioned to facilitate global energy transition by maximizing production of remaining oil and gas reserves, supporting renewable energy developments and decommissioning end-of-life oil and gas fields.  For more information about Helix, please visit our website at www.helixesg.com.

Non-GAAP Financial Measures

Management evaluates performance and financial condition using certain non-GAAP measures, primarily EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt.  We define EBITDA as earnings before income taxes, net interest expense, gains or losses on extinguishment of long-term debt, gains and losses on equity investments, net other income or expense, and depreciation and amortization expense.  Non-cash impairment losses on goodwill and other long-lived assets are also added back if applicable.  To arrive at our measure of Adjusted EBITDA, we exclude the gain or loss on disposition of assets, acquisition and integration costs, the change in fair value of the contingent consideration and the general provision (release) for current expected credit losses, if any.  We define Free Cash Flow as cash flows from operating activities less capital expenditures, net of proceeds from sale of assets. 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 EBITDA, 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 EBITDA, 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 EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt differently from the way we do, which may limit their usefulness as comparative measures. EBITDA, 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.

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 share repurchase authorization or program; the COVID-19 pandemic and oil price volatility and their respective effects and results; our protocols and plans; our current work continuing; the spot market; our ability to identify, effect and integrate acquisitions, joint ventures or other transactions, including the integration of the Alliance acquisition; our spending and cost management efforts and our ability to manage changes; our strategy; visibility and future utilization; energy transition or energy security; any projections of financial items including projections as to guidance and other outlook information; future operations expenditures; our plans, strategies and objectives for future operations; our ability to enter into, renew and/or perform commercial contracts; developments; our environmental, social and governance (“ESG”) initiatives; future economic conditions or performance; 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 the results and effects of the COVID-19 pandemic and actions by governments, customers, suppliers and partners with respect thereto; market conditions; results from acquired properties; demand for our services; the performance of contracts by suppliers, customers and partners; 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; our ability to secure and realize backlog; the effectiveness of our ESG initiatives and disclosures; human capital management issues; complexities of global political and economic developments; geologic risks; volatility of oil and gas prices and other risks described from time to time in our 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 Dec. 31,				Year Ended Dec. 31,
(in thousands, except per share data)	2022		2021		2022		2021
	(unaudited)				(unaudited)
Net revenues	$	287,816	$	168,656	$	873,100	$	674,728
Cost of sales		256,452		174,017		822,484		659,335
Gross profit (loss)		31,364		(5,361)		50,616		15,393
Loss on disposition of assets, net		—		—		—		(631)
Acquisition and integration costs		(315)		—		(2,664)		—
Change in fair value of contingent consideration		(13,390)		—		(16,054)		—
Selling, general and administrative expenses		(22,787)		(21,499)		(76,753)		(63,449)
Loss from operations		(5,128)		(26,860)		(44,855)		(48,687)
Equity in earnings (losses) of investment		—		—		8,262		(1)
Net interest expense		(4,333)		(5,301)		(18,950)		(23,201)
Loss on extinguishment of long-term debt		—		(12)		—		(136)
Other income (expense), net		14,293		(52)		(23,330)		(1,490)
Royalty income and other		406		269		3,692		2,873
Income (loss) before income taxes		5,238		(31,956)		(75,181)		(70,642)
Income tax provision (benefit)		2,529		(6,048)		12,603		(8,958)
Net income (loss)		2,709		(25,908)		(87,784)		(61,684)
Net loss attributable to redeemable noncontrolling interests		—		—		—		(146)
Net income (loss) attributable to common shareholders	$	2,709	$	(25,908)	$	(87,784)	$	(61,538)
Earnings (loss) per share of common stock:
Basic	$	0.02	$	(0.17)	$	(0.58)	$	(0.41)
Diluted	$	0.02	$	(0.17)	$	(0.58)	$	(0.41)
Weighted average common shares outstanding:
Basic		151,425		150,170		151,276		150,056
Diluted		151,425		150,170		151,276		150,056

Comparative Condensed Consolidated Balance Sheets

	Dec. 31, 2022		Dec. 31, 2021
(in thousands)	(unaudited)
ASSETS
Current Assets:
Cash and cash equivalents	$	186,604	$	253,515
Restricted cash		2,507		73,612
Accounts receivable, net		212,779		144,137
Other current assets		58,699		58,274
Total Current Assets		460,589		529,538
Property and equipment, net		1,641,615		1,657,645
Operating lease right-of-use assets		197,849		104,190
Deferred recertification and dry dock costs, net		38,778		16,291
Other assets, net		50,507		18,364
Total Assets	$	2,389,338	$	2,326,028
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable	$	135,267	$	87,959
Accrued liabilities		73,574		91,712
Current maturities of long-term debt		38,200		42,873
Current operating lease liabilities		50,914		55,739
Total Current Liabilities		297,955		278,283
Long-term debt		225,875		262,137
Operating lease liabilities		154,686		50,198
Deferred tax liabilities		98,883		86,966
Other non-current liabilities		95,230		975
Shareholders' equity		1,516,709		1,647,469
Total Liabilities and Equity	$	2,389,338	$	2,326,028

Helix Energy Solutions Group, Inc.

Reconciliation of Non-GAAP Measures

	Three Months Ended						Year Ended
(in thousands, unaudited)	12/31/2022		12/31/2021		9/30/2022		12/31/2022		12/31/2021
Reconciliation from Net Income (Loss) to Adjusted EBITDA:
Net income (loss)	$	2,709	$	(25,908)	$	(18,763)	$	(87,784)	$	(61,684)
Adjustments:
Income tax provision (benefit)		2,529		(6,048)		6,500		12,603		(8,958)
Net interest expense		4,333		5,301		4,644		18,950		23,201
Loss on extinguishment of long-term debt		—		12		—		—		136
Other (income) expense, net		(14,293)		52		20,271		23,330		1,490
Depreciation and amortization		40,096		35,288		35,944		142,686		141,514
Gain on equity investment		—		—		(78)		(8,262)		—
EBITDA		35,374		8,697		48,518		101,523		95,699
Adjustments:
Loss on disposition of assets, net		—		—		—		—		631
Acquisition and integration costs		315		—		762		2,664		—
Change in fair value of contingent consideration		13,390		—		2,664		16,054		—
General provision (release) for current expected credit losses		90		67		624		781		(54)
Adjusted EBITDA	$	49,169	$	8,764	$	52,568	$	121,022	$	96,276
Free Cash Flow:
Cash flows from operating activities	$	49,712	$	18,865	$	24,650	$	51,108	$	140,117
Less: Capital expenditures, net of proceeds from sale of assets		(28,514)		(936)		(2,803)		(33,504)		(8,271)
Free Cash Flow	$	21,198	$	17,929	$	21,847	$	17,604	$	131,846
Net Debt:
Long-term debt including current maturities	$	264,075	$	305,010	$	263,581	$	264,075	$	305,010
Less: Cash and cash equivalents and restricted cash		(189,111)		(327,127)		(164,774)		(189,111)		(327,127)
Net Debt	$	74,964	$	(22,117)	$	98,807	$	74,964	$	(22,117)

EX-99.2

Exhibit 99.2

February 21, 2023 Fourth Quarter 2022 Conference Call

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 share repurchase authorization or program; the COVID-19 pandemic and oil price volatility and their respective effects and results; our protocols and plans; our current work continuing; the spot market; our ability to identify, effect and integrate acquisitions, joint ventures or other transactions, including the integration of the Alliance acquisition; our spending and cost management efforts and our ability to manage changes; our strategy; visibility and future utilization; energy transition or energy security; any projections of financial items including projections as to guidance and other outlook information; future operations expenditures; our plans, strategies and objectives for future operations; our ability to enter into, renew and/or perform commercial contracts; developments; our environmental, social and governance (“ESG”) initiatives; future economic conditions or performance; 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 the results and effects of the COVID-19 pandemic and actions by governments, customers, suppliers and partners with respect thereto; market conditions; results from acquired properties; demand for our services; the performance of contracts by suppliers, customers and partners; 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; our ability to secure and realize backlog; the effectiveness of our ESG initiatives and disclosures; human capital management issues; complexities of global political and economic developments; geologic risks; volatility of oil and gas prices and other risks described from time to time in our 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 2

• Executive Summary (pg. 4) • Operational Highlights by Segment (pg. 11) • Key Financial Metrics (pg. 21) • 2023 Outlook (pg. 26) • Environmental, Social and Governance (pg. 33) • Non-GAAP Reconciliations (pg. 34) • Questions and Answers 3 PRESENTATION OUTLINE

Executive Summary 4

HELIX: AN ENERGY TRANSITION AND SUSTAINABILITY MODEL Helix’s focus since 2009 has been on the end of life of existing oil & gas reservoirs and supporting offshore wind development Maximizing Remaining Reserves in Existing Reservoirs Well and Field Abandonment and Decommissioning Offshore Wind Development Support Helix serves three core markets: Maximizing Remaining Reserves in Existing Reservoirs • Production enhancement and problem remediation via subsea well intervention • Provision of a low-cost production unit for mature reservoir production • Equity assumption of end-of-life reserves with management and maximization until abandonment Well and Field Abandonment and Decommissioning • Plug and abandonment of subsea and dry tree wells upon depletion of production • Abandonment of subsea architecture • Abandonment and removal of shallow water production facilities Offshore Wind Development Support • Trenching and burial of power cables • UXO and boulder clearance site preparation 5

6 EXECUTIVE SUMMARY ($ in millions, except per share amounts, unaudited) Three Months Ended 12/31/22 12/31/21 9/30/22 12/31/22 12/31/21 Revenues 288 $ 169 $ 273 $ 873 $ 675 $ Gross profit (loss) 31 $ (5) $ 39 $ 51 $ 15 $ 11% (3)% 14% 6% 2% Net income (loss)1 $ (26) 3 $ (19) $ (88) $ (62) $ Diluted earnings (loss) per share 0.02 $ (0.17) $ (0.12) $ (0.58) $ (0.41) $ Adjusted EBITDA2 Business segments 65 $ 25 $ 69 $ 169 $ 136 $ Corporate, eliminations and other (16) (16) (16) (48) (39) Adjusted EBITDA2 $ 9 49 $ 53 $ 121 $ 96 $ Cash and cash equivalents3 $ 254 187 $ 162 $ 187 $ 254 $ Net Debt2 $ (22) 75 $ 99 $ 75 $ (22) $ Cash flows from operating activities 50 $ 19 $ 25 $ 51 $ 140 $ Free Cash Flow2 $ 18 21 $ 22 $ 18 $ 132 $ Year Ended 1 Net income (loss) attributable to common shareholders 2 Adjusted EBITDA, Free Cash Flow and Net Debt are non-GAAP financial measures; see non-GAAP reconciliations below 3 Excludes restricted cash of $3 million at 12/31/22 and 9/30/22 and $74 million at 12/31/21 Amounts may not add due to rounding

7 Financial Results • Net income of $3 million, $0.02 per diluted share • Adjusted EBITDA1 of $49 million • Operating cash flows of $50 million • Free Cash Flow1 of $21 million Operations • Commenced Trident decommissioning campaign on Siem Helix I and extended Petrobras contract at market rates on Siem Helix 2 in Brazil • Strong utilization in the GOM and North Sea • Completed campaign in Nigeria on the Q7000; commenced paid mobilization to Asia Pacific for contracted decommissioning projects in 2023 • Secured contract extension on Helix Producer I • Deepwater well decommissioning contract awarded by Shell in Brazil on Q7000 expected to begin 2024 • Continued contribution from Helix Alliance • Acquired three subsea trenchers and interest in two intervention riser systems, approx. $27 million; sanctioned second boulder grab EXECUTIVE SUMMARY – Q4 2022 HIGHLIGHTS 1 Adjusted EBITDA and Free Cash Flow are non-GAAP financial measures; see non-GAAP reconciliations below

8 Financial Results • Net loss of $88 million, $(0.58) per diluted share • Adjusted EBITDA1 of $121 million • Operating cash flows of $51 million • Free Cash Flow1 of $18 million Operations • Acquired the Alliance group of companies on July 1 for $119 million cash plus earnout due 2024, reported in new Shallow Water Abandonment segment • Acquired interest in three producing wells from Murphy in the Thunder Hawk Field on August 25 for nominal cash received and assumption of P&A obligations • Extended charters on Siem Helix 1 and Siem Helix 2 vessels • Executed term charter agreements in Robotics for Shelia Bordelon in the U.S. and Horizon Enabler in the North Sea • Deployed new boulder grab, acquired three subsea trenchers, an interest in two intervention riser systems and sanctioned second boulder grab • Strong utilization and rate improvements in the GOM and North Sea • Completed Nigeria campaign on Q7000; commenced paid mobilization to Asia Pacific for contracted decommissioning projects in 2023 Awards • Secured contract extension on Helix Producer I through at least June 2024 • Awarded and commenced Trident decommissioning campaign on Siem Helix I and extended Petrobras contract at market rates on Siem Helix 2 • Awarded multi-year contract with Shell in the GOM • Deepwater well decommissioning contract awarded by Shell in Brazil on Q7000 expected to begin 2024 EXECUTIVE SUMMARY – 2022 FULL YEAR HIGHLIGHTS 1 Adjusted EBITDA and Free Cash Flow are non-GAAP financial measures; see non-GAAP reconciliations below

9 Well Intervention • Well Intervention vessel fleet utilization 97% • 97% in the GOM • 99% in the North Sea and West Africa • 92% in Brazil • 15K IRS and 10K IRS idle during quarter Robotics • Robotics chartered vessels utilization 96% • 332 total vessel days (68 spot vessel days) • 160 days trenching utilization • ROV and trencher utilization 58% Shallow Water Abandonment • 71% Liftboat, OSV and crewboat combined utilization • 63% Diving support vessel (DSV) utilization • Epic Hedron idle • 1,247 days P&A and coiled tubing (CT) systems utilization representing 65% utilization on 15 marketable P&A systems and six CT systems Production Facilities • Helix Producer I operated at full rates during quarter • Continued production from Droshky and full quarter contribution from Thunder Hawk wells EXECUTIVE SUMMARY – Q4 2022 SEGMENTS

10 Q4 2022 • Cash and cash equivalents of $187 million (excludes $3 million of restricted cash) • Liquidity1 of $285 million • Long-term debt2 of $264 million • Net Debt3 of $75 million $200 Million Share Repurchase Authorization • Expect to align repurchases with FCF generation; Initially targeting repurchases of 25% of FCF • Expect to be flexible with our method of distribution over time • Repurchase program should allow us to deploy cash to shareholders while maintaining adequate cash and liquidity to fund operations and investment opportunities EXECUTIVE SUMMARY – BALANCE SHEET 1 Liquidity at December 31, 2022 is calculated as the sum of cash and cash equivalents and available capacity under Helix’s ABL facility and excludes restricted cash of approximately $3 million 2 Net of unamortized issuance costs 3 Net Debt is non-GAAP financial measure; see non-GAAP reconciliations below

Operational Highlights By Segment 11

BUSINESS SEGMENT RESULTS 12 ($ in millions, unaudited) Three Months Ended Year Ended 12/31/22 12/31/21 9/30/22 12/31/22 12/31/21 Revenues Well Intervention 168 $ 119 $ 144 $ 524 $ 517 $ Robotics 49 41 56 192 137 Shallow Water Abandonment1 - 57 67 125 - Production Facilities 28 20 18 82 69 Intercompany eliminations (14) (12) (13) (50) (48) Total 288 $ 169 $ 273 $ 873 $ 675 $ Gross profit (loss) % Well Intervention 6 $ 3% $ (18) (15)% $ 2 1% $ (40) (8)% $ (21) (4)% Robotics 9 18% 5 13% 14 24% 38 20% 13 10% Shallow Water Abandonment1 7 11% 17 - 26% 24 19% - Production Facilities 11 38% 7 36% 7 37% 31 37% 25 36% Eliminations and other - - - (1) (2) Total 31 $ 11% $ (5) (3)% $ 39 14% $ 51 6% $ 15 2% Utilization Well Intervention vessels 97% 56% 87% 80% 67% Robotics vessels 96% 99% 98% 95% 97% Robotics assets (ROVs and trenchers) 58% 38% 66% 53% 36% Shallow Water Abandonment vessels1 67% - 80% 73% - Shallow Water Abandonment systems1 65% - 59% 62% - 1 Shallow Water Abandonment includes the results of Helix Alliance beginning July 1, 2022, the date of acquisition; system utilization includes 21 marketable spreads for the quarter ended December 31, 2022 and 20 marketable spreads for the quarter ended September 30, 2022 Amounts may not add due to rounding

WELL INTERVENTION – GULF OF MEXICO • Q5000 – 100% utilized in Q4; performed production enhancement scopes on four wells under a multi-year campaign for Shell with a customer-provided 15K IRS • Q4000 – 94% utilized in Q4; completed a two-well production enhancement scope for one customer, followed by a single-well abandonment scope for another customer, commenced a two-well production enhancement scope for another customer; vessel incurred scheduled maintenance during the quarter • 15K IRS rental unit – idle in Q4 • 10K IRS rental unit – idle in Q4 13

WELL INTERVENTION – NORTH SEA AND WEST AFRICA / ASIA PACIFIC • Well Enhancer – 100% utilized in Q4; performed production enhancement operations on five wells for two customers • Seawell – 97% utilized in Q4; performed live and suspended well decommissioning operations for several customers; commenced continuous suspended well decommissioning campaign included 13 wells for five customers • Q7000 – 100% utilized in Q4 operating in Nigeria into December; subsequently commenced paid transit to Asia Pacific; 21 days paid transit days are being presented as utilized although related transit and mobilization fees and costs are deferred during Q4 and are expected to be recognized in 2023 14

WELL INTERVENTION – BRAZIL • Siem Helix 1 – 87% utilized in Q4; completed ROV work scopes for Trident Energy in November; subsequently transitioned to a two-year decommissioning campaign for the same customer and performed decommissioning scopes on three wells in the Campos basin • Siem Helix 2 – 98% utilized in Q4; performed production enhancement scopes on three wells and decommissioning scopes on three wells for Petrobras in the Santos and Campos basins; subsequently commenced two-year contract extension with Petrobras in December 15

WELL INTERVENTION – UTILIZATION 16 59% 93% 92% 83% 88% 58% 74% 89% 86% 80% 88% 97% 63% 40% 31% 9% 38% 63% 71% 38% 42% 44% 79% 99% 99% 99% 99% 98% 100% 100% 72% 52% 87% 88% 99% 92% 0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% Q1 20 Q2 20 Q3 20 Q4 20 Q1 21 Q2 21 Q3 21 Q4 21 Q1 22 Q2 22 Q3 22 Q4 22 Gulf of Mexico¹ North Sea / West Africa² Brazil³ All Well Intervention Vessels 1 Gulf of Mexico includes the Q4000 and Q5000 2 North Sea / West Africa includes the Seawell, Well Enhancer and Q7000 3 Brazil includes the Siem Helix 1 and Siem Helix 2

ROBOTICS • Grand Canyon II (Asia Pacific) – 100% utilized in Q4 performing long-term decommissioning project offshore Thailand • Grand Canyon III (North Sea) – 100% utilized in Q4; performed renewables trenching operations for three customers and oil and gas trenching for two customers • Shelia Bordelon (GOM) – 91% utilized in Q4; performed boulder removal project for one customer supporting wind farm operations offshore U.S. east coast using the IROV boulder grab and ROV survey support for another customer in the GOM • Spot Vessels – 68 days of spot vessel utilization during Q4 on Horizon Enabler performing renewables trenching operations for one customer and oil and gas trenching for another customer • Trenching – 160 total days of trenching operations on Grand Canyon III and Horizon Enabler, including 101 days of renewables trenching and 59 days of oil and gas trenching 17

ROBOTICS UTILIZATION 18 405 499 450 336 165 236 358 419 323 370 376 332 42 119 154 92 72 84 90 90 66 81 176 160 34% 34% 37% 32% 24% 36% 43% 38% 35% 53% 66% 58% - 50 100 150 200 250 300 350 400 450 500 0% 10% 20% 30% 40% 50% 60% 70% Q1 20 Q2 20 Q3 20 Q4 20 Q1 21 Q2 21 Q3 21 Q4 21 Q1 22 Q2 22 Q3 22 4Q22 Vessel Days Trenching Days ROV utilization (%)¹ 1 ROV utilization included 44, 42 and 40 work class ROVs during 2020, 2021 and 2022, respectively, and four trenchers during 2020 and 2021; IROV boulder grab placed into service end of Q3 2022 and two trenchers placed into service December 1, 2022

SHALLOW WATER ABANDONMENT • Offshore – • Liftboats – ten liftboats with combined utilization of 69% in Q4 performing make safe, well abandonment, pipeline abandonment, CT, wireline, construction support, production support and dive support operations • OSVs – six OSVs and one crew boat with combined utilization of 74% in Q4 • Energy Services – 1,106 days utilization, or 80%, over 15 marketable P&A systems in Q4, six CT systems with combined 141 days, or 26%, utilization in Q4 • Diving & Heavy Lift – three diving support vessels with combined utilization of 63% in Q4; heavy lift barge seasonally idle during Q4 19

SHALLOW WATER ABANDONMENT UTILIZATION 20 1 Vessels utilization includes ten liftboats, six OSVs, one crew boat, three diving support vessels, and one heavy lift derrick barge 2 Systems utilization includes six coiled tubing systems and 14 and 15 marketable P&A systems during Q3 2022 and Q4 2022, respectively, with the ability to scale up to 20 P&A systems 72% 95% 86% 41% 71% 30% 69% 74% 63% 0% 80% 26% 0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% Liftboats¹ OSVs and Crew Boat¹ Diving Vessels¹ Heavy Lift Derrick Barge¹ P&A Systems² Coiled Tubing Systems² Q3 22 Q4 22 The graph below presents the utilization statistics of the Helix Alliance vessels following their acquisition on July 1, 2022

Key Financial Metrics 21

DEBT INSTRUMENT PROFILE Total funded debt1 of $271 million at 12/31/22 • $30 million Convertible Senior Notes due 2023 – 4.125% • $200 million Convertible Senior Notes due 2026 – 6.75% • $41 million MARAD Debt – 4.93% • Semi-annual amortization payments through maturity in Q1 2027 $0 $50 $100 $150 $200 $250 2023 2024 2025 2026 2027 Principal Payment Schedule at 12/31/22 ($ in millions) CSN 2023 CSN 2026 MARAD $38 1 Excludes $7 million of remaining unamortized debt issuance costs 22 $9 $210 $9 $5

DEBT & LIQUIDITY PROFILE ($ in millions) 1 Cash includes cash and cash equivalents but excludes restricted cash at December 31, 2019, 2021 and 2022 of $54 million, $74 million and $3 million, respectively 2 Long-term debt through December 31, 2020 was net of unamortized discounts and issuance costs; beginning January 1, 2021, long-term debt is net of issuance costs only 3 Liquidity is calculated as the sum of cash and cash equivalents and available capacity under Helix’s $100 million ABL facility and excludes restricted cash 4 Net Debt is a non-GAAP financial measure; see non-GAAP reconciliations below $267 $279 $208 $291 $254 $187 $(496) $(440) $(406) $(350) $(305) $(264) $348 $426 $380 $452 $305 $285 $(229) $(161) $(143) $(58) $22 $(75) ($500) ($400) ($300) ($200) ($100) $0 $100 $200 $300 $400 $500 Cash¹ Long-term debt² Liquidity³ Net Debt⁴ 12/31/17 12/31/18 12/31/19 12/31/20 12/31/21 12/31/22 23

Revenue Free Cash Flow2 1 Helix Alliance revenue has been included for periods beginning July 1, 2022 (date of acquisition) 2 Adjusted EBITDA and Free Cash Flow are Non-GAAP financial measures; see non-GAAP reconciliations below $740 $752 $734 $675 $873 $29 $58 $22 $(62) $(88) ($100) ($80) ($60) ($40) ($20) $0 $20 $40 $60 $80 $0 $200 $400 $600 $800 $1,000 2018 2019 2020 2021 2022 Revenue Net Income (loss) Net income (loss) Adjusted EBITDA2 FIVE-YEAR TREND1 ($ IN MILLIONS) $162 $180 $155 $96 $121 $60 $31 $80 $132 $18 $0 $50 $100 $150 $0 $50 $100 $150 $200 2018 2019 2020 2021 2022 Adjusted EBITDA ² Free Cash Flow² 24

REVENUE DISPERSION ($ IN MILLIONS) By Geography By Segment 1 1 25 1 Revenue percentages net of intercompany eliminations 2 Helix Alliance revenue has been included in Shallow Water Abandonment segment beginning July 1, 2022 (date of acquisition) 37% 39% 42% 34% 51% 28% 29% 28% 23% 10% 26% 26% 18% 15% 19% 6% 19% 9% 6% 10% 6% 9% 10% $0 $200 $400 $600 $800 $1,000 2018 2019 2020 2021 2022 United States Brazil United Kingdon West Africa Other 74% 73% 71% 74% 58% 17% 19% 21% 16% 18% 14% 9% 8% 8% 10% 10% $0 $200 $400 $600 $800 $1,000 2018 2019 2020 2021 2022 Production Facilities Shallow Water Abandonment² Robotics Well Intervention 52% 35% 10% 3% Production Maximization Decommissioning Renewables Other By Market Strategy1 Year-Ended 2022

2023 Outlook 26

27 2023 OUTLOOK: FORECAST ($ in millions) 2023 2022 Outlook Actual1 Revenues $ 1,020 - 1,200 873 $ Adjusted EBITDA2 210 - 250 121 Free Cash Flow2 110 - 150 18 Capital Additions3 50 - 70 69 Revenue Split: Well Intervention $ 640 - 690 524 $ Robotics 190 - 230 192 Shallow Water Abandonment1 170 - 250 125 Production Facilities1 70 - 80 82 Eliminations (50) (50) Total $ 1,020 - 1,200 873 $ 1 2022 Actual includes the results of Helix Alliance in the Shallow Water Abandonment segment beginning July 1, 2022 and Thunder Hawk Field production in the Production Facilities segment beginning August 25, 2022 2 Adjusted EBITDA and Free Cash Flow are non-GAAP financial measures; see non-GAAP reconciliations below 3 Capital Additions include regulatory certification costs for our vessels and systems as well as other capital expenditures

28 2023 OUTLOOK – WELL INTERVENTION • Q4000 (Gulf of Mexico) – contracted through mid-March followed by approximate 75-day dry dock; subsequent awarded work through Q3; identified opportunities and visibility for remainder of 2023 • Q5000 (Gulf of Mexico) – contracted work on Shell multi-year campaign to mid-Q3, with approximate 35- day regulatory underwater inspection late-Q1; subsequent awarded work into Q4; identified opportunities and visibility for remainder of 2023 • IRS rental units (Gulf of Mexico) – 15K IRS has visibility for work during Q3; 10K IRS available second half of year in spot market; two 10-K deep water riser systems (DRS) acquired late 2022 with one system expected to be available Q1 and the other in 2024 • Well Enhancer (North Sea) – contracted work into Q4 and utilization expected through remainder of 2023; 10-day maintenance docking during Q1 • Seawell (North Sea and Europe) – contracted work through end of year and into 2024; 21-day maintenance docking during Q1 • Q7000 (Asia Pacific) – undergoing planned maintenance docking in Malaysia prior to approximately 200 days contracted in 2023 performing decommissioning campaigns offshore New Zealand and Australia expected to commence Q2 and to be completed by end of year • Siem Helix 1 (Brazil) – under decommissioning contract for Trident Energy in the Campos Basin offshore Brazil through remainder of 2023 • Siem Helix 2 (Brazil) – contracted decommissioning and production enhancement work for Petrobras in various Basins offshore Brazil through remainder of 2023

29 • Grand Canyon II (Asia Pacific) – continuing to perform contracted decommissioning and ROV support work offshore Thailand into Q3 with expected good utilization; expected to remain in Thailand well into 2H and should have close to full utilization for remainder of 2023 • Grand Canyon III (North Sea) – performing trenching in northwest Africa through Q1 followed by contracted trenching scopes into Q4, with strong utilization expected for 2023 • Shelia Bordelon (U.S.) – continuing to perform ROV survey support project expected into 2Q; vessel subsequently in spot market expected to have strong utilization over remainder of 2023 with visibility for projects in the Gulf of Mexico and on the U.S. east coast for possible wind farm projects • Horizon Enabler (North Sea) – flexible charter, expected to perform seasonal trenching campaign Q2 through Q3; identified projects in Q4 in both Mediterranean and North Seas with good utilization expected for remainder of 2023 • Glomar Wave (North Sea) – three-year charter commenced January 2023 with committed and optional days each year; contracted beginning March into Q2; expected to perform renewables site clearance projects performing both UXO survey and boulder removal work • Trenchers (Global) – seven trenchers entering 2023, with expected three working trencher spreads, two in the North Sea and one in Asia Pacific, with remaining trenchers in spot market available to work on third-party vessels including the i-Plough trenching system for U.S. east coast operations; expect good utilization on five trenchers during 2023 • ROVs (Global) – expect strong utilization in all three regions during 2023 2023 OUTLOOK – ROBOTICS

30 • Offshore • Liftboats - expected high utilization on eight to 10 liftboats throughout 2023 • OSVs – expected seasonality in activity, with stronger mid-year utilization and seasonal slowdown Q1 and Q4 • Energy Services • P&A Systems – expected strong utilization for 12 to 15 P&A systems throughout 2023 • Coiled Tubing Systems – expected utilization on one to three coiled tubing systems throughout 2023 • Diving & Heavy Lift • DSVs – diving services expected to be seasonal, with stronger mid-year utilization and seasonal slowdown Q1 and Q4 • Epic Hedron – heavy lift barge with identified opportunities during seasonal mid-year period 2023 OUTLOOK – SHALLOW WATER ABANDONMENT

2023 Capital additions are forecasted at approximately $50 - $70 million: • Primarily maintenance capex related to regulatory recertification costs of our vessels and systems, which are reported in operating cash flows • Approximately $14 million of capital additions carried over from prior year Balance Sheet • Our total funded debt1 is expected to decrease by $38 million (from $271 million at December 31, 2022 to $233 million at December 31, 2023) as a result of scheduled principal payments during 2023 • Remaining principal payment of $30 million of convertible senior notes due September 2023 2023 OUTLOOK: CAPITAL ADDITIONS & BALANCE SHEET 1 Excludes unamortized issuance costs 31

32 • We plan to continue momentum on the three legs of our Energy Transition business model: production maximization, decommissioning and renewables • Expected continued strong operating and free cash flows • Maintenance capex anticipated to be approximately $50 million annually • Well Intervention • Expect strong Gulf of Mexico and North Sea intervention markets in 2024 with good utilization and rates • Seawell contracted backlog into 2024 • Expect continued operations in Brazil in 2024: • Q7000 under decommissioning contract with Shell in Brazil in 2024 • Siem Helix 1 on long-term contract with Trident in Brazil into Q4 2024, with options to extend • Siem Helix 2 on long-term contract with Petrobras through late 2024 • Robotics • Anticipate continued strong renewables trenching market • Expect continued renewables site clearance project opportunities, including in the U.S. markets • Continued tight ROV market • Shallow Water Abandonment • Expected ongoing strong Gulf of Mexico shallow water decommissioning market • Balance Sheet • No significant debt maturities until 2026 • Alliance earnout first half of 2024 BEYOND 2023

ENVIRONMENTAL, SOCIAL AND GOVERNANCE Environmental • Our business supports the responsible transition from a carbon based economy through a three pronged strategy of maximizing remaining oil and gas reserves, abandonment and decommissioning end of life wells and applying the techniques and technologies proven in offshore oil and gas fields to offshore renewables and wind farms. These efforts are published in greater detail in our 2022 Corporate Sustainability Report, a copy of which is available on our website at https://www.helixesg.com/about-helix/our-company/corporate-sustainability/. Social • Human capital management is a priority at Helix. Investment in our human capital through competitive compensation and attractive benefits, including training and development is necessary to attract and retain talent Governance • Our Board is actively engaged on ESG strategy including health, safety, social, environmental and climate change issues through an open dialogue with management coupled with regular reports from key team members • Our Board has been significantly refreshed over the past four years adding five new members. As part of such long standing refreshment process, in 2022 the Corporate Governance and Nominating Committee remained engaged in a search for additional independent directors with the diverse characteristics sought by the Board, and in September the Board added two new gender and ethnically diverse members 33

Non-GAAP Reconciliations 34

35 NON-GAAP RECONCILIATIONS ($ in thousands, unaudited) Three Months Ended Year Ended 12/31/22 12/31/21 9/30/22 12/31/22 12/31/21 Adjusted EBITDA: Net income (loss) 2,709 $ (25,908) $ (18,763) $ (87,784) $ (61,684) $ Adjustments: Income tax provision (benefit) 2,529 (6,048) 6,500 12,603 (8,958) Net interest expense 4,333 5,301 4,644 18,950 23,201 Loss on extinguishment of long-term debt - 12 - - 136 Other (income) expense, net (14,293) 52 20,271 23,330 1,490 Depreciation and amortization 40,096 35,288 35,944 142,686 141,514 Gain on equity investment - - (78) (8,262) - EBITDA 35,374 $ 8,697 $ 48,518 $ 101,523 $ 95,699 $ Adjustments: Loss on disposition of assets, net - $ - $ - $ - $ 631 $ Acquisition and integration costs 315 - 762 2,664 - Change in fair value of contingent consideration 13,390 - 2,664 16,054 General provision (release) for current expected credit losses 90 67 624 781 (54) Adjusted EBITDA 49,169 $ 8,764 $ 52,568 $ 121,022 $ 96,276 $ Free Cash Flow: Cash flows from operating activities 49,712 $ 18,865 $ 24,650 $ 51,108 $ 140,117 $ Less: Capital expenditures, net of proceeds from sale of assets (28,514) (936) (2,803) (33,504) (8,271) Free Cash Flow 21,198 $ 17,929 $ 21,847 $ 17,604 $ 131,846 $ Net Debt: Long-term debt and current maturities of long-term debt 264,075 $ 305,010 $ 263,581 $ 264,075 $ 305,010 $ Less: Cash and cash equivalents and restricted cash (189,111) (327,127) (164,774) (189,111) (327,127) Net Debt 74,964 $ (22,117) $ 98,807 $ 74,964 $ (22,117) $

36 NON-GAAP AND OTHER DEFINITIONS Non-GAAP Financial Measures We define EBITDA as earnings before income taxes, net interest expense, gains or losses on extinguishment of long-term debt, gains and losses on equity investments, net other income or expense, and depreciation and amortization expense. Non-cash impairment losses on goodwill and other long-lived assets are also added back if applicable. To arrive at our measure of Adjusted EBITDA, we exclude the gain or loss on disposition of assets, acquisition and integration costs, the change in fair value of the contingent consideration and the general provision (release) for current expected credit losses, if any. We define Free Cash Flow as cash flows from operating activities less capital expenditures, net of proceeds from sale of assets. 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 EBITDA, 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 EBITDA, 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 EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt differently from the way we do, which may limit their usefulness as comparative measures. EBITDA, 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.

Thank you 37

EX-99.3

EXHIBIT 99.3

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								23-002
Date: February 20, 2023		Contact:	Erik Staffeldt
			Executive Vice President & CFO

Helix Announces $200 Million Share Repurchase Program

HOUSTON, TX – Helix Energy Solutions Group, Inc. (“Helix”) (NYSE: HLX) announced today that its Board of Directors has authorized a repurchase program for up to $200 million of Helix’s issued and outstanding shares.

Owen Kratz, President and Chief Executive Officer of Helix, stated, “We view this program as a prudent use of our capital and an excellent opportunity to deploy cash to shareholders.  We expect to generally align execution of the program with our cash flow generation.  With a strong balance sheet, ample liquidity, a robust offshore services market recovery, and our current expectation that we will generate strong cash flows, the share repurchase program should allow us to increase shareholder value while maintaining adequate cash and liquidity to fund our operations and investment opportunities.”

Repurchases under the new program may be made in open market purchases in compliance with Rule 10b-18 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), privately negotiated transactions, or plans, instructions or contracts established under Rule 10b5-1 of the Exchange Act.  The manner, timing and amount of any purchase will be determined by management based on an evaluation of market conditions, stock prices, liquidity and other factors.  The program does not obligate Helix to acquire any particular amount of common stock and may be modified or superseded at any time.

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 full-field decommissioning operations.  Our services are centered on a three-legged business model well positioned to facilitate global energy transition by maximizing production of remaining oil and gas reserves, supporting renewable energy developments and decommissioning end-of-life oil and gas fields.  For more information about Helix, please visit our website at www.helixesg.com.

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 share repurchase authorization or program; the COVID-19 pandemic and oil price volatility and their respective effects and results; our protocols and plans; our current work continuing; the spot market; our ability to identify, effect and integrate acquisitions, joint ventures or other transactions, including the integration of the Alliance acquisition; our spending and cost reduction plans and our ability to manage changes; our strategy; visibility and future utilization; energy transition or energy security; any projections of financial items including projections as to guidance and other outlook information; future operations expenditures; our plans, strategies and objectives for future operations; our ability to enter into, renew and/or perform commercial contracts; developments; our environmental, social and governance (“ESG”) initiatives; future economic conditions or performance; 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 the results and effects of the COVID-19 pandemic and actions by governments, customers, suppliers and partners with respect thereto; market conditions; results from acquired properties; demand for our services; the performance of contracts by suppliers, customers and partners; 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; our ability to secure and realize backlog; the effectiveness of our ESG initiatives and disclosures; human capital management issues; complexities of global political and economic developments; geologic risks; volatility of oil and gas prices and other risks described from time to time in our reports filed with the Securities and Exchange Commission (“SEC”), including our most recently filed Annual Report on Form 10-K and in our other filings with the SEC, 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.

XML

Document and Entity Information	Feb. 21, 2023
Document and Entity Information [Abstract]
Document Type	8-K
Document Period End Date	Feb. 21, 2023
Entity File Number	001-32936
Entity Registrant Name	HELIX ENERGY SOLUTIONS GROUP, INC.
Entity Incorporation, State or Country Code	MN
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	TX
Entity Address, Postal Zip Code	77043
City Area Code	281
Local Phone Number	618-0400
Written Communications	false
Soliciting Material	false
Pre-commencement Tender Offer	false
Pre-commencement Issuer Tender Offer	false
Title of 12(b) Security	Common Stock, no par value
Trading Symbol	HLX
Security Exchange Name	NYSE
Entity Emerging Growth Company	false
Entity Central Index Key	0000866829
Amendment Flag	false