Greetings and welcome to the Fourth Quarter 2019 Earnings Conference Call. During today’s presentation, all participant lines will remain in a listen-only mode. Afterwards, we will conduct a question-and-answer session with instructions to follow. [Operator Instructions] Please note, this conference is being recorded, Tuesday, February 25, 2020.It is now with pleasure that I turn today's conference over to Mr. Erik Staffeldt, CFO. Please go ahead, sir.

Good morning, everyone. And thanks for joining us today on our conference call for our fourth quarter and full year 2019 earnings release. Participating on the call this morning are; Owen Kratz, our CEO; Scotty Sparks, our COO; Ken Neikirk, our General Counsel; and myself.Hopefully, you've had an opportunity to review our press release and the related slide presentation released last night. If you do not have a copy of these materials, both can be accessed through the Investors page on our website at www.helixesg.com.The press release can be accessed under the Press Releases tab, and the slide presentation can be accessed by clicking on today's webcast icon. Before we begin our prepared remarks, Ken Neikirk will make a statement regarding forward-looking information. Ken?

During this conference call, we anticipate making certain projections and forward-looking statements based on our current expectations. All statements in this conference call or in the associated presentation other than statements of historical facts are forward-looking statements and are made under the Safe Harbor provisions of the Private Securities Litigation Reform Act of 1995.Our actual future results may differ materially from our projections and forward-looking statements due to a number and variety of factors including those set forth in slide two and our most recently filed Annual Report on Form 10-K and in our other filings with the SEC.Also during this call, certain non-GAAP financial disclosures may be made. In accordance with SEC rules, the final slide of our presentation provides reconciliations of certain non-GAAP measures to comparable GAAP financial measures. These reconciliations along with this presentation, the earnings press release, our annual report and a replay of this broadcast are available under the -- for the -- Investors section of our website at www.helixesg.com. Owen?

Good morning, everyone. Now we're going to start on slide five through eight today, which provide a high-level summary of our results. The fourth quarter marked the start of the seasonal slowdown of activity in the North Sea affecting both our Well Intervention and Robotics segments. The slowdown typically starts in November and runs into April.The seasonality can be seen in our results as revenues in Q4 were $171 million down from $213 million in Q3. The decline in revenue decreased our gross profit to $27 million or 16% compared to $55 million or 26% in Q3. For the quarter, we recorded a net income of $8 million compared to net income of $32 million in Q3. The reduction in revenue resulted in lower EBITDA of $33 million in Q4 compared to $66 million in Q3.Considering the seasonal slowdown, our teams operated efficiently during the fourth quarter managing high asset utilization and quickly reducing costs during the idle periods. For 2019, revenues improved by $12 million to $752 million. Our gross profit improved by $16 million to $138 million. Net income increased by $29 million to $58 million. And our EBITDA increased to $180 million into 2019 from $162 million in 2018.Operating cash flow for the year was $170 million, resulting in free cash flow of $31 million. This marks the third consecutive year of sequential growth in revenue and EBITDA.There were many factors that drove our operational and financial improvements in 2019. It all starts with our employees. I thank our employees for their efforts and high level of execution in 2019. Executing safe and efficient operations for our customers has established us as a leader in the industry.Second, we recognize these are challenging times, but we're starting to see signs of an improving offshore well intervention market. The North Sea region has been consistent since 2017 with predictable activity and relatively stable oil prices driving our markets.In the Gulf of Mexico, 2019 saw increased activity offshore with immediate benefit to our vessel utilization. We're seeing signs of rational financial returns, driving investment decisions, leading our customers back offshore.Third, we benefited from the creative contracting that allowed us the flexibility to schedule Droshky work during scheduled gaps limiting our downside. And last, we've benefited from the improving cost structure in our Robotics segment. We have right-sized the business for the current market conditions positioning us to generate positive returns.From a balance sheet perspective, our cash level at year end was $208 million with an additional $54 million in restricted cash associated with the short-term LC. For 2019, we generated $170 million of operating cash, invested $141 million in capital expenditures with net free cash flow of $31 million. Our net debt at the end of the year was $143 million.I'll now turn the call over to Scotty for an in-depth discussion of our operating.

Thanks Owen. Good morning, everyone. Moving on to slide 10, the fourth quarter was a good period considering we commenced the slower winter seasonal period and completed this year's BP campaign at the end of Q3. We achieved good results across the fleet with excellent operational performance in regards to safety, uptime and well work efficiency, achieving revenue uptime of 98% against contracted base.Year ended with strong safety performance by far one of our best years in regards to safety statistics. We are proud of our Helix team's performance this year. Our staff and our partners such as Schlumberger have been outstanding.In the fourth quarter, we achieved revenues of $171 million compared to $213 million in the third quarter. Gross profit margin was 16% resulting in profits of $27 million, decreasing from 26% and $55 million gross profits in Q3.Considering the start of the seasonal winter period, we obtained high levels of utilization. The Well Intervention fleet achieved utilization of 92% globally, Gulf of Mexico had 95%, North Sea had 82%, and Brazil at 98% utilization. The Robotics chartered vessel fleets achieved utilization of 73% globally.In the Gulf of Mexico the Q5000 completed the abandonment of our second well of four trustee wells and then completed work for two customers prior to commencing its five-year regulatory inspection and maintenance program in late December.Q4000 worked for two customers completing two abandonment scopes for one customer, and then a number of production enhancement scopes for another.The North Sea business performed well, working for four customers, with the well enhancer work in most of the quarter, working through to the end of December, and the Seawell working into December before entering seasonal warm stacked. Performance in Brazil was strong again both vessels performed very well, achieving high utilization of 98%, with excellent uptime.The…

Thanks, Scotty. Slide 17 outlines our debt instruments and their principal maturity profile. I'll leave this slide for your reference and move on to slide 18. This slide provides an update on key balance sheet metrics, including long-term debt and net debt levels as of year-end.Our net debt in Q4 increased $143 million from $127 million in Q3. The increase in net debt during Q4 is primarily attributable to the $69 million final shipyard payment for the delivery of the Q7000.Our total capital investments of $95 million partially offset by $80 million of cash generated from operations. Our cash position at year end was $208 million, excluding $54 million of restricted cash. Our year end net debt-to-book capitalization was 8%.Moving over to slide 20 for a discussion on our 2020 outlook. For 2020, we're providing guidance in certain key financial metrics from our forecast. We're forecasting revenues in the range of $820 million -- $820 million to $890 million, EBITDA in a range of $180 million to $210 million.We expect to generate free cash flow between $110 million to $150 million. We expect to spend approximately $50 million in capital expenditures, primarily maintenance capital. These ranges include some key assumptions and estimates. Any significant variation for these key assumptions and estimates could cause our results of fall outside the results provided.We are assuming a good first year utilization on the Q7000. We expect the vessel primarily to work in West Africa. The vessel is currently under contract into Q2 and we continue to pursue opportunities in West Africa and other regions. We expect the 2020 North Sea Well Intervention market to maintain a consistent level of activity with continued seasonal fluctuations.The Seawell has completed its regulatory maintenance during Q1 with work scheduled for early March. The Well Enhancer completed its…

Thanks Erik. The narrative given includes an awful lot of detail. I'll try and give a bit of a broader context. We're still in a challenging market. Demand is off the bottom as our rates, but services are still oversupplied and still needs to be absorbed before we see significant rate increases, although, they are moving up slowly. While we're doing well on utilization, we have a lot of leverage to rates, which we expect to -- that will occur over the coming years.We have believed for some time now that we will have to enter a long gradual recovery. We see 2020 continuing to be challenging, but signs that supply-demand may hold promise for a meaningfully stronger 2021. However, we're not sitting back and waiting on a recovery story.In this current market, investors want capital discipline, free cash flow yield along with manageable debt. Our first priority was to complete our last legacy capital project the Q7000. It's now working in Nigeria at least into Q2.We have potential work identified that would keep the vessel in Africa for the remainder of 2020. We're also negotiating work that could potentially fill the first half of 2021. And after that we're in talk for a contract that could last for most of 2022. None of that work is signed up yet, but timing for bringing the Q7000 to market seems to be right and the last of our major capital projects is now complete.Going forward, our capital expenditure should run about $30 million to $50 million per year primarily for maintenance capital. In 2020, we've anticipated the seasonally slow Q1 in the North Sea.So, we took advantage of this to complete the maintenance periods on both the North Sea vessels. BP has elected to take their 270 days on the Q5000…

Thanks, Owen. Operator, at this time, we'll take any questions.

Thank you, very much. [Operator Instructions] And our first question comes from the line of Vaib Vaishnav. Please proceed with your question.

Hey good morning and thank you for taking my questions. Well, I guess, you guys talked about going -- trying to get to net debt zero by the end of 2020. Just trying to think about what your plans are for 2020 -- 2022 and 2023 converts, given like I think like about $100 million of debt payments you have scheduled already for 2020?

Okay. So I think that in general, we are definitely driving our debt levels lower. We have those scheduled payments that you talked about $100 million here in 2020. We recognize that we have the converts out there in 2022 and 2023.Based on our current market conditions and our current performance, I think our expectations would be to keep that as a permanent level or semi-permanent form of debt out there. So, our intentions would be more than likely to roll our balances associated with our converts in '22 and '23 in some type of instrument.

Okay, that's very helpful. Can you talk about the rate improvements that you're seeing in North Sea? And what you are seeing in Gulf of Mexico?

I'll take that. Yes, we have definitely seen a slight increase in the North Sea. Our utilizations improved slightly as well. But last year, we had a couple of legacy contracts that were at lower rates. So, we've readjusted to market in the North Sea. And in the Gulf of Mexico, very slight increases, but again the utilization is quite -- by having the droshky fair bid that means any gaps that come up, we can fill them with the -- with our own work. So starting to see rates improvements. There's still an oversupply of rigs.And so, it's looking more for us in 2021 wherein we'll see a larger increase in our rates as those rigs drop off. Also, a lot of the work that we've undertaken, our contracts up this year was a bit at the end of 2019 at lower rates as well, not as high rates as we could properly achieve. So we're seeing an increase, it's moving in the right direction, but it's slowly.

Okay. And I guess you guys have done a very good job on cost cuts and also all the hedges going -- like most of the hedges going away. Just trying to think, if there are any other cost-saving opportunities that you guys see going forward?

Well, I'll take that for you Scotty, because -- while we've been doing really well on the structural costs that you mentioned. I think, operationally, there's still room for us. There's room for us to improve on our downtime allowances, which I think we're making great gains on, but there's still more improvement.Also, I think, there's -- there are areas with our strategic partner Schlumberger to cross train and integrate crewing and manning requirements that would allow us to lower personnel on board on each of our vessels. We're in the early stages of that.But that would be a significant cost reduction; it will just take some time for us to get all that training in place, the legal aspects covered and to affect it on the vessels. But I'd see over time that being a significant cost savings.

All right. That’s all for me. Thank you for taking my questions again.

Our next question comes from the line of Ian Macpherson. Please proceed with your question.

Thanks. Good morning, everyone. Owen, it's good to hear that the calendar is filling for Q7000. You mentioned, you're bidding multiple work that goes out into next year. And I assume that you are working more at a level of missionary pricing this year that you would hope to improve upon, as you move into the vessels second tranche of work.I wanted to confirm that with you and get, just, a directional sense of what you're hoping for with regard to the Q7000 as it moves from this year into next year from a pricing perspective?

Well, I believe, that if you go back, we've always been saying that the Q7000, the first year it comes out. It's a big uncertainty on the introduction to the market and they could contribute to EBITDA anywhere from zero to $20 million.I think, we've taken a -- I think, we definitely put out some introductory rates in order to get it started. And operationally, we're probably being conservative, although, on its first well. It's performing very well. And hopefully that will continue.Going forward, now, the pricing that we are putting out for the Q7000. And in fact all of the pricing for 2021 and beyond is at substantially higher rates. Whether or not we're able to achieve that or not, we'll see. But right now there's a lot of interest in the Q7000 at the rates that we've given, which are higher than the introductory rate that we're working under.And I don't know, we'll see. We're far along in the producers expressing their interest. We're far along in some cases in actually negotiating the Ts and Cs of the contracts. So, things are looking fairly bright for the Q7000.

Good. Good. Good to hear that. Thanks. I also wanted to ask about your looming renewals in Brazil, I think SH1 hits the four-year mark a little more than a year from now right? So I just wanted to get the updated outlook there on when you're in your real window and how the expectations are shaping up on that front?

Yes. The Q5000 with the team will be coming up next year for renewal. We're in discussions very informal. The producers don't want to start formal discussions until a certain time before the termination or the renewal period of the contract. But the vessel has been working very well. I think BP is very ecstatic about the results that have been achieved with the vessel. We're talking about changing the relationship where we actually can offer greater value through the contract. So, all the discussions are leaning positive.In Brazil, I have even less worry. I think in Brazil the two vessels have consistently been rated in their top two rigs. We were the Marine Contractor of the Year last night -- last year for Petrobras. They are adding rigs. I think it's obvious that they need the vessels and the vessels are performing extremely well.I mean to work on 28 wells in a year is a pretty phenomenal comparison when you look at what a rig could do. So, the efficiency story has been brought into their improvement. So, I'm very confident about the negotiations with Petrobras.

Good stuff. Thanks Owen. I'll pass it over.

And our next question comes from the line of Praveen Narra. Please proceed with your question.

Hey good morning guys. I guess if I could follow-on to Ian's question on the Q7. When you think about the interest in the out years for that vessel, are you seeing it from anybody who wants it for a single customer? Or do you expect it to kind of get to multiple customers and back-to-back work?

I think the way we're looking at the Q7 right now is that we have two vessels in each region the Northeast, Gulf of Mexico, and Brazil. We want to penetrate West Africa, Asia-Pacific, and of course, Brazil is also a growing market. We're actually running out of availability. As soon as the rig market tightens up, I think that spells good things for us.We sort of view the Q7000 as our swing vessel right now. I think strategically, we have reason to want to build the backlog in all of those regions. While it's building, I see the Q7000 being a swing vessel transiting from region-to-region. And if you remember one of the reasons we built it the way we did is, that it does have a high transit speed for a semisubmersible. So, that allows us application to that purpose perfectly.The one disappointment I'll go in though for transparency is the vessel was originally built for a producer that said they had a lot of work in the North Sea. As things have turned out here three years later, the greater interest and the greater demand is actually in the other regions than it is in the North Sea. I think that will come eventually. But for the next few years, I actually see here being more of an international asset transiting from region-to-region.

That's super helpful color. Sorry.

More multi-client but longer campaigns, it's not going to be bouncing around on 15, 20-day jobs. So all of the negotiations we have now are for a longer 100 to 180-day type campaigns.

That's very helpful. And then as we kind of think about the guidance and the profitability between Well Intervention and Robotics. How should we -- there's a lot of moving parts of robotics obviously, you have some cost structure benefits as well as trenching it's a low point. Can you talk about whether you expect Robotics profitability to be up year-over-year? And then also can you talk about the trenching outlook for the next couple of years?

Yes I'll take that. So we expect Robotics to be modestly higher than in 2019. We are seeing the benefits of the cost structure, the Grand Canyon gets returned, has been returned. So that comes out of cost base. The hedges have come off the cost base.We are seeing a flatter trend in year, it's a lower tranche but it actually goes down to some of the renewables, cables that have been in manufacturing the timing of those coming out to when those installations happen and our trenchant obviously follows behind that.Going into 2021, we have work contracted from 2021 out to 2023. Higher volumes of work that we see in 2020. And we're still in the still the oil and gas bid season for trenching ongoing right now. So, it's -- we're not saying that all the trenching date are taken for the assets right now.We're also seeing an expansion geographically for trenching where our trenching market for renewables has primarily been North Sea and where the wind farms are or the regulatory fishing compliance has been required.We're starting to see a lot more tender activity for APAC and where wind farms are coming off Taiwan and other is in the Middle East. So trenching essentially is flat to the year this year. But its outlook that's very good for us.

And much of that -- it's a little different from the oil and gas market that we've been in where we're subject to sort of short-term visibility The wind farm market, we have long-term visibility on the work that's out there. It's perhaps a bit lumpy but it's far more certain -- our outlook is far more certain. So, when we say that 2020 is an off year. It's going to be less than 2019 but we have concrete visibility on the outlying years of it coming back.

Absolutely. Thank you very much guys.

Thank you.

And our next question comes from the line of Michael Sabella. Please proceed with your question.

Hey, good morning all. Thanks for taking my call. If we just kind of think about the rig market more broadly, a lot of stress on the balance sheets for a lot of the driller peers, which really is restricting them from deploying capital to reactivate rigs. How do you anticipate this playing out kind of over the longer term? So have you seen the ability to push rates a little harder than you normally would have given that backdrop?

Well you really have to break the rig market down into the different categories of rigs. All floaters aren't the same. The harsh environment rigs are enjoying quite a revival in the rig rates. The lower fourth gen, fifth gen not so much. There's still an oversupply. I think the rig rates are far from the point that warrants reactivation.The costs incurred plus the longer that the rigs sit, the higher the reactivation costs rise, so I would not expect to see -- I'm not even going to put a number on it. But I don't expect to see that many rigs reactivated coming back into the market. I think just the utilization rate right now, I believe is at about 60%, 80% on marketed rates.We're on the cusp of where you can see meaningful rate increases. I don't see the underlying fundamentals of the oil and gas market in 2020 driving that beyond -- beyond that trigger point. But I do -- am seeing signs that 2021 could see a tightening of the supply-demand that spurs the market to actually exceed that trigger point.I still don't think though even in 2021, you're going to see rig rates high enough to warrant the capital cost or the reactivation. So I see 2021, 2022 not being maximum rig rates, but that rig rates that really mean -- meaningful profitability increase for us.

Yeah. Great. That's really helpful. And then when we kind of circle back to capital allocation. So you guys haven't passed talked about the possibility of buyback. If you kind of approach net debt-neutral territory keeping in mind that we really need to know more about 2021 before making firm decisions. Is there a leverage target that you all are comfortable sharing that would kind of allow you to start returning cash to shareholders and just sort of talk about where M&A fits into that kind of broader capital allocation decision?

Yeah, I think from -- this is Erik. I think from the -- from our standpoint, we are driving the company towards the net debt zero. I think there's multiple factors rather than just leverage. I think that as Owen mentioned, we definitely do need visibility in 2021.Obviously, a stronger market would allow us to be slightly more aggressive in our leverage position, a weaker market. I think we would obviously be more conservative. So, there's multiple factors, but obviously in general, we are operating as a low leverage -- low leverage company.

I don't mind sharing some specifics on it. A company our size, I believe can and perhaps should for efficiency carried about $300 million to $400 million in gross debt. You -- I prefer to see us around that $300 million. I'm not a high debt guy. But in a strong market, I can see $400 million, but more likely $300 million.Liquidity-wise, I think between $300 million and $400 million of liquidity. And our intent is to try and carry about a $200 million cash balance. That's sort of where we feel very comfortable that we could face anything that the market may throw at us.Now, as far as how that plays into returning value to shareholders. I think that gets into the question previously raised about what do we do with the converts out there, and our capital structure. Do we create a softer lending creating greater liquidity, and therefore a greater ability to return the value to shareholders early. I think that depends off strongly on how robust we really think 2021 is going to be.As I said by putting all of these dry docks into the first quarter of this year, we're setting up a strong 2021. We're starting the discussions on the contract renewals. And if all that goes well then our confidence builds in our ability to share value back with the shareholders.

That's great. Thanks so much guys.

[Operator Instructions] Our next question comes from the line of James Schumm [ph]. Please proceed with your question.

Hey. Thanks and good morning.

Good morning.

So most of -- most of my questions have been answered, but is there any way you can help us think about the economics of the renewable energy support project with two vessels in the North Sea. How should investors be modeling as we're thinking about this?

Okay. I'll take that one. First of all, it's much lower revenue type work, its two small vessels doing a site clearance. So each of these large wind farms that are out there you have to remove any unexploded ordinance or any bonus that get in the way of the field development.So, it's small about removing those problems for the wind farm operator and then doing site surveys. So the revenue on each boat is around $40,000 a day. And the margins are flexible depending on the type of work we're doing at $15,000 a day.The project we have is the first for us. It started very well. Both vessels have been working from December and our target to go well into the third quarter of this year. But because of that, we are seeing that that's an area that we could enter in. There's not a lot more bid activity coming up. And it's something that we're really focusing in is better returns into RVs on the customers vote. So we're looking to diversify our robotics offering.

Okay, great. Thanks for that. And then the 15K IRS unit, it looks like it's lined up for one well in the second quarter. I think in the past two years you've talked about utilization close to the 50% range for the year. Is the expectation right now that this would be a lot lower in 2020? Is this -- should we -- I mean, I know it's early but should we be thinking of this in more of a 30% to 40% range?

Right now I would expect it to be in line with previous years. We have one well for one client. But it's lined up to go back to a legacy client that's come back to us in the second half of the year, and we do expect utilization to be somewhat similar.

Okay, great. Thanks guys. Appreciate it.

[Operator Instructions] There do not appear to be any further questions in the queue at this time. I'll turn the call back to you. Please continue.

Thanks for joining us today. We very much appreciate your interest and participation and look forward to having you on our first quarter 2020 call in April. Thank you.

That does conclude today's presentation. We thank you for your participation and ask that you please disconnect your lines. Have a great rest of the day everyone.