Helix Energy Solutions Group, Inc. (HLX) Q3 2010 Earnings Report, Transcript and Summary

Ladies and gentlemen, thank you for standing by and welcome to the review of the third quarter 2010 results with investors’ conference call. During the presentation all participants will be in a listen-only mode. Afterwards we will conduct a question and answer session. (Operator Instructions) As a reminder this conference is being recorded Thursday October 28, 2010. It is now my pleasure to introduce Mr. Tony Tripodo, Chief Financial Officer. You may proceed sir.

Thank you France. Good morning everyone and thanks for joining us today. Joining me today here at Helix is Owen Kratz, our CEO, Bart Heijermans, our Chief Operating Officer, Johnny Edwards, our Executive Vice President of Oil & Gas, Alisa Johnson, our General Counsel; Lloyd Hajdik, our Senior VP of Finance and let me also introduce to everyone Steven Powers who reports for Lloyd and he will be taking over the IR duties from Kim and Wallace as we have asked Cameron to devote 100% of his time to marketing which is his primary responsibility. At the end of this call Steven will provide you with his contact information. 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 Investor Relations tab on our website at www.helixesg.com. The press release can be accessed under recent news and a slide presentation can be accessed by clicking on today’s webcast icon. Before we begin our prepared remarks, Alisa Johnson will make a statement regarding forward-looking information. Alisa?

Thank you. 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 fact 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 in forward-looking statements due to a number and variety of factors including those set forth in our slide two, and in our Annual Report on Form 10-K for the year ended December 31, 2009 and any subsequent Form 10-K. Also during this call, certain non-GAAP financial disclosures may be made. In accordance with SEC rules, the final slides of our presentation materials provide a reconciliation of certain non-GAAP measures to comparable GAAP financial measures. The reconciliation along with this presentation, earnings press release, our Annual Report and a replay of this broadcast are available on our website. Tony will now make some opening remarks.

Okay. Moving on to slide four which summarizes our second quarter results and our commentary will focus on sequential quarterly results comparing quarter three to quarter two. Quarter three’s revenues increased 31% to $393 million in revenues from $299 million in quarter two, primarily owing to a substantial increase in subsidy construction activity both pipelay and ROV as well as the deployment of the Helix Producer 1 on Macondo spill containment activities. Gross operating margins were flat quarter to quarter at 22% as high margins driven by the Helix Producer 1 were offset by negative off margins realized by both Caesar and the Normand Clough on their initial jobs. Quarter three produced EPS at $0.25 a share which was up from the $0.18 of operating EPS in the second quarter. Moving to slides five and six, along with the earnings improvement we generated 143 million of EBITAX in the third quarter, up from the 141 million in the second quarter. Furthermore we improved our bottom line results despite the fact that we incurred $20 million of losses combined on the Caesar’s first pipelay job and the Normand Clough’s first well intervention job. We expect the performance in these vessels to improve in the future. In addition the well Enhancer was out of service for 61 days during quarter three undergoing a core tubing upgrade and we absorbed 9 million of hurricane risk premiums related to our weather derivative instrument. Bart will add some color on these mentioned projects later. I will defer discussion here on gas side of the business to Johnny Edwards later. Obviously the big news here is the commencement of Phoenix production which began on October 19th. We’re also pleased to report that our liquidity position increased to 700 million by the end of quarter three as our cash balances increased to 325 million at quarter end and our revolving credit facility remains unused. Moving on to slide seven and looking forward to quarter four you should expect the contracting service business to step down from Q3 levels. Primary reasons include the return of the Helix Producer 1 to the Phoenix field and thus for inter-company use, slower ROV business as the significant trenching jobs we worked on during quarter three have been completed and we have seen activity levels in these sub sector taper off and again normal season declines in the winter season as well as Caesar downturn due to vessel upgrade work. In contrast with the start up of production in the Phoenix field in mid October, we expect oil and gas production increase in Q3 levels and thus of course find increase in revenues for this segment. Bart will get into the contracting service business again later in more detail. Over to slide eight. Slide eight updates the guidance we provided on our last conference call. With the benign hurricane season behind us and Phoenix production now online, we have now moved our production up to a higher end of last quarter’s guidance to 45 billion cubic feet equivalent for the full year. While there is opportunity for us to beat this number, given the unforeseen circumstances that always seem to arise in this business, we believe it’s prudent to stick with the 45DCF8. The same reasons we cited for production our EBIDTA guidance has now been refined to 450 million compared to our previous guidance of (inaudible). CapEx is projected at 200 million for the year and that assume some EMP projects get underway so it may not hit that level. With our hedges in place we’re forecasting realization on commodity prices to be approximately $76 for oil and slightly under $6 for natural gas and with our hedges in place we have projected fourth quarter production fully hedged. Now for some color on the contracting services business I will turn the next few slides over to Bart.

Thanks Tony, good morning everybody. Let’s move to slide 9. Helix contracting services 13 owned and chartered vessels enjoyed strong utilization in the quarter. Three of our vessels, the Q4000, Helix Producer 1 worked exclusively for BP on the Macondo response in the Gulf of Mexico. The Caesar completed its first project 47 miles of 20 inch pipeline in shallow water in the Gulf of Mexico. This project was bid very competitively in a weak market by various pipelay contractors. Helix was successful in securing this work with the main objective of establishing a track record for the Caesar. Lower than expected productivity of the third party supplied automatic welding system and some vessel start of issues with a new marine crew caused Helix to incur a loss on this project. The pipelay work was completed in the third week of September and this project is thankfully behind us. Helix’s Robotic subsidiary (inaudible) offshore performed very well in the quarter and so did the Seawell well intervention vessel in the North Sea. The well Enhancer was out of service for the majority of the quarter which was planned and required to complete the core tubing upgrades. The vessel entered its first North Sea well with core tubing in early October and is currently working in the North Sea deploying this technology. [Well of Southeast Asia] is using the Normand Clough on the Lufeng well P&A project for CNOOC. The main objective of this job is to seek utilization for the Normand Clough and to introduce deepwater live well intervention to offshore China but several setbacks in the field, weather downtime and some [down low] issues and equipment problems have caused this project to take longer than scheduled and hence we have booked a loss in the quarter. Moving to slide 10. Slide 10 shows the various operating modes of the Q4000 on the Macondo response. The vessel played a key role in all the response activities and we’re very proud of the work performed by our employees on our three vessels involved in the response and our employees acted – were active in the unified area (inaudible) center and in the Helix offices. Slide 11. Helix contracting services delivered record revenues of 313 million and a gross profit of 87 million for the quarter despite the mentioned losses on the Macondo and Lufeng project and two months of scheduled downtime for the well Enhancer. Slide 12 shows the equity and earnings contribution of independent help, Marco Polo, TOB and CloughHelix JV companies. The Normand Clough achieved in excess of 80% utilization for the quarter, (inaudible) well ops Southeast Asia on the Lufeng project. Slide 13. As commented earlier, our vessel utilization was high in a relatively weak market. Credit to our employees in our service business units. On slide 14, contracting services fourth quarter outlook is shown. We’re expecting high utilization for our well ops vessels but the lower margins mainly due to the Q4000 performing lower margin well P&A work in the flex trend area off the Gulf of Mexico where the vessel competes with cheaper rigs. The ROV support vessels experienced a seasonal slowdown. The Caesar is expected to complete her second five-day project, an 18 mile long, 18 inch pipeline for EOG Trinidad in early November after which the vessel will return to Ingleside for some equipment upgrades. The vessel is performing better on this project than she was on the Macondo project. The Express and the Inteprid are fully booked for the remaining of the quarter. Now for our oil and gas business I will turn it over to Johnny.

Good morning. Please turn over to slide 15. Both slides 15 and 16 provide the financial highlights for the third quarter for oil and gas. Moving beyond those financial highlights in these slides, the highlight for oil and gas is really the Phoenix field starting up on October 19th across the HP1 floating production unit. This is an historic event for the ERT and Helix teams. The HP 1 is the first deepsea floating production unit to operate in the Gulf of Mexico and as you may remember earlier this year that Danny oil well started up in the Bushwood field and is the longest oil tieback in the Gulf of Mexico. These two events this year are things that the ERT and Helix teams are very proud of. The startup of the Phoenix field has progressed very well considering the field has been shut in for over five years when Hurricane Rita destroyed the TLP. After about a week here of what I call normal startup activity, the field is currently producing today from two wells, producing over 10,000 barrels of oil and 14 million and with that, our BOE net is about 7250 per day. We have a third well expected to come on and we’ve been up and down but we’ll have that third well on in early November and a fourth well should begin producing in late November, bringing the total fill rate on a net basis to over 10,000 barrels of oil a day equivalent net to ERT and even with the scheduled gas pipeline shut in for (inaudible) move to early December and normal field starter problems, the Phoenix field should add at least 2.5 BCFE net to ERT in the fourth quarter of 2010. With the addition of the Phoenix production, ERT should produce more than the 45 BCFE Tony mentioned as an estimate for 2010. The Phoenix field is considered – has considerable development opportunity remaining beyond the four existing producer-able wells. Our Little Burn well was drilled and cased and all it needs to be completed and tied in to the HP1. The Little Burn completion should add another 5,000 barrels of oil equivalent net to ERT and beyond Little Burn there are additional wells to be drilled to recover updip added PUD reserves. ERT plans to file for permits in 2010 to complete Little Burn in 2011 and drill at least one additional Phoenix well in 2011 if permitting and rig availability allows. The completion of Little Burn and the drilling opportunities in the field should provide strong oil production rates from the Phoenix field for at least three years. The BOE MRE replacement for the MMS has released new rules on acceleration of P&A liabilities in the Gulf of Mexico which will have some impact on the timing of our platform and well abandonments. We are preparing our initial response to the BOE but we do not expect to be significantly impacted in 2011 by the new rules. We have been very proactive in taking care of abandonment obligations over the past three years and we were already planning another aggressive abandonment program in 2011. Many of the additional wells that were P&A required in 2011 are under the new rules will be covered by an Escrow fund already in place and fully funded for the abandonment of one of our major shelf fields. Moving over to slide 17, slide 17 represents our hedge position, both volumes and prices for the remainder of 2010 and 2011. The 11.7 BCFE hedge for the remainder of 2010 reflects an almost fully hedged position for the fourth quarter 2010 and we have now hedged 22.3 BCFE for 2011. Now I’ll turn it over to you Lloyd.

Thanks Johnny. Slide 18 reflects a synopsis of our F3 position, interest in our cash position beginning of the year. We’ve reduced net debt levels since the beginning of 2010 by some $60 million to currently about $1.03 billion and we expect further reductions in net debt by the end of this year. As Tony mentioned earlier our liquidity level at September 30th now stands at approximately $700 million. Slides 20 and 21 are the non-GAAP reconciliation schedules presented for your reference and I’ll not go over those schedules in detail on the call. At this time I’d like to turn the call back over to Owen for his closing comments.

Good morning everyone. We continued to operate in some pretty interesting times. Helix continues to improve both financially and operationally and we still have significant room for further improvement. With regard to our efforts to market our oil and gas business, we’re presently evaluating the response to our data room process and thus feel it’s inappropriate to comment at this stage on the process. Obviously market dynamics and economic conditions have not been ideal. However, we remain committed to the divestiture of our oil and gas at a price we believe provides full value to our shareholders. This quarter reflects the fact that we can generate earnings even without earnings contribution from production and in spite of the current debt service as well as some project losses that we feel we’ll be able to resolve going forward and on top of all that the enhancer being out of service. I would like to say though that the production is generating positive cash and the cost of our debt overall is very good. We’ve curtailed capital spending on the oil and gas side for the past two years as we focus on our balance sheet. Going into 2011 and assuming we continue to own the MP business, we will look to spend capital on the producing fields but only where we must. Our goal will be to constrain capital spending to within the cash flow generated by the production while holding annual production levels and prove reserve levels relatively flat and we believe at this point through the positive value in our portfolio to have this – be able to have this kind of a gold record requires some real value in the portfolio. We believe this is possible and we should still be able to generate free cash flow due to the high levels of oil production which should be going to 60/40 oil to gas with Phoenix online. Some of these results depend on what unfolds with the government regulatory uncertainties. The drilling moratorium has been lifted but that’s largely a sideshow to the real issue which is permitting. We intend to seek drilling permit for one completion and one new exploratory well as well as some none-op interests in one or two other wells. The permitting process could impact our production rates and our stated goals for 2011. It is still uncertain as to when permitting will resume at a level consistent with historic trends. I personally believe that it’s at least the second quarter before we see a meaningful level of permitting occurring as the regulatory requirements for the permits are worked through One but not the only issue for permitting is the requirement for blowout containment. The BOEMRE has not yet clearly stated what that requirement is to be in detail. Other permitting regulatory uncertainties exist around worst case discharge calculations, oil spill cleanup capacity, BPA study requirements as well as new requirements on drillers and equipment. It’s a matter of just working through these issues with the BOEMRE. On the service side, given our heavy involvement in the Macondo well, Helix should be well positioned to offer an acceptable containment solution with the Q4000 and the HP1 both for ourselves and the industry. We’ve been making efforts with the NWCC, BP, the Independents as well as presentations in Washington with regard to this. The high profile given to the Q4000 and the HP1 capabilities during the Macondo incident does have at the very least indirect positive implications for Helix. Hopefully our credibility has been greatly enhanced with regard to well intervention in the Gulf of Mexico and elsewhere. This is important because we’ve been in a competition for the start oil cat B vessel tender. This is essentially an enhanced version of the Q4000 vessel for use on an eight year contract by Statoil in Norway. The technical submissions are in and commercial submissions are due on November 15th with awards stated to be around year end. Well intervention expansion is the direction that we would like to take Helix in and if we win this award, this new vessel would be a significant step forward, clearly establishing the business identity that we’re working towards, maintaining and extending our clear leadership in the deepwater well intervention service market. Moving forward, the outlook for Helix is mixed but not as bad as some review Helix as the Gulf of Mexico centric construction contractor might think. Actually 60% of Helix service revenues are generated outside of the Gulf of Mexico. The global market is oversupplied with lower demand than usual so it’s probably best described as being active but with some pressure on margins. We may see some margin compression in our Robotics business but we don’t expect it to be severe. Second point, our well intervention business is especially niche business. Near term it’s not affected by cyclicality as it’s a life of field service and producers are more and more recognizing the value of intervention for production enhancement. There are interested new competitors lurking but the learning curve is steep and regulatory issues may be a further barrier to entry. Helix is the clear leader. The greater near term threat for our well intervention for the Q4000 would be from rig pricing pressures. However, even with lower rig rates, given the greater efficiency of Helix methodologies we don’t see imminent pressure on our rigs. Quality of service will still be the most important factor governing rates going forward in our opinion. We anticipate a strong 2011 in our well intervention business. Now our production facilities business is totally unaffected by the current Gulf of Mexico situation which leaves our significant exposure to the Gulf of Mexico other than the production issues that I mentioned on permitting being our three pipelay assets which work a fair amount in the Gulf of Mexico. Our options for pipelay in response to any potential softening and demand in the gulf are first to seek more international work, second to seek alternative service, for example the Intrepid is an excellent MSV and it can be a light well intervention vessel as well and then the final point there on the express we feel very confident that there will be enough work load for us to keep the express fully utilized. I said potential softening because we have a solid client base and it’s also possible that we see less competition in the construction pipelay market from foreign contractors deciding to focus elsewhere. WE have strong stable businesses in well intervention Robotics and facilities. We feel we have our oil and gas production issues under good control, subject of course to the regulatory uncertainty. Financially we’re comfortable. We’re aware that sustained growth will require capital and the same time we must continue to reduce debt levels. Our most fundamental strategy going forward is to grow well intervention while lowering debt which is accomplished by selling off our oil and gas assets. Our intent is to execute this strategy as the market opportunities allow us to. With that I’ll turn it back over to Steven. Oh, I’m sorry, we’ll go to questions first and then we’ll give Steven a chance to provide his contact information

Thank you. (Operator Instructions). Our first question from the line of Jim Rollyson from Raymond James. You may proceed. Jim Rollyson – Raymond James: Good morning guys.

Good morning Jim. Jim Rollyson – Raymond James: Owen, I guess just to start with the Q4000 pre Macondo had a fair amount of work in backlog for it running through much of 2010. I think kind of last quarter your update commentary was there's – a lot of that work was still around and you weren't sure if you would lose some during the course of when you guys were working for BP on the Macondo project. Can you give us kind of an update on how the backlog stretches out into next year for the Q and how that looks?

Why don’t I let Bart do that since he’s probably closest to the most recent update on the backlog? Jim Rollyson – Raymond James: Sure.

Yes. The backlog is still there. We didn’t lose anything and we’ve added additional backlog. So at this moment I mean the queue looks pretty good until mid 2011 and the feasibility is there that we feel pretty comfortable that 2011 is going to be another good year for the Q4000. Jim Rollyson – Raymond James: Great, thanks for that. On the HP1, now that this quarter transitions from getting paid as a non-third party to working on Phoenix, Tony, maybe you can give us some kind of guidance on how revenues and margins look as we go – you know, you are going to have bigger eliminations and what have you, but just kind of trying to understand how that flows from 3Q to 4Q from an income statement perspective.

Okay very good and it’s a good question Jim. Obviously the tradeoff here is HP1 revenues turning in our company. For the most part there is still 30% of the HP1’s revenues because of the 30% non-op interest held that flows through the bottom line. But still the tradeoff is the loss of 100% of the HP1evenues versus Phoenix production and from a P&A standpoint I’ll just say that that’s a negative tradeoff mainly because of high BBNA rates on the Phoenix field. I mean you don’t lose all of the profitability but you lose some, I would say that and from a cash standpoint it’s fairly neutral. Phoenix field will generate a fair amount of cash flow. Jim Rollyson – Raymond James: Sure, and then just my last question, I guess. Given Phoenix is on, you've got a couple of wells ramping up hopefully to the four. When you think about that in terms of your big picture production profile, since you guys are spending kind of minimal CapEx these days, do we look at a scenario where 4Q kind of 1Q production is the peak and then it kind of rolls steadily lower over time, assuming you don't ramp up CapEx? Is that a fair assessment?

Well I’ll answer that Jim. I think number one we are going to ramp up CapEx next year in the MP business to as Owen said within the confines of the cash flow we’re generating from the business. We want to spend some more CapEx and again assuming we continue to own the business and we really look at 2011 at this point. We’re not done with our budgeting process but we’re looking at it as being probably a fairly neutral year in terms of production year on year. Jim Rollyson – Raymond James: Okay, great. Good quarter.

A lot of ups and down. It depends on hurricanes, et cetera but it should be fairly neutral. Jim Rollyson – Raymond James: Perfect, good quarter guys.

Our next question from the line of Roger Read with Natixis Bleichroeder. You may proceed.

Good morning.

Morning Roger

I guess – and I apologize because I got pulled away for just a second Owen. But when you were talking about well intervention expansion potential, can you give me a little more of an idea of what that is? I mean Is it acquiring a vessel? Is it just more work for the Q4000 or are we talking about even potentially building kind of a next-generation Q4000 here?

Well we’ve just recently added the coiled tubing onto the enhancer so that should have positive implications on next year’s rate from our North Sea assets. As I mentioned also that we are looking at the potential of putting light well intervention on the Intrepid for the Gulf of Mexico and currently we’re not in the light intervention market there, we’re in the heavy intervention market with the Q4000. The main focus of expansion though is for the last year we’ve been working in competition a feed study project for Statoil in competition with [Auker] and [Sitam] for building what’s essentially a Q4000 on steroids for the Norwegian market through an eight year contract. When we first built the Q4000, it was our intention to have multiple copies because we really believe that that’s the vessel of the future for our industry. So this is sort of a renewed effort in that direction.

Okay, so not necessarily a changed up in the way you've been looking at the market?

No, but the Statoil vessel would be a new build vessel.

Right, right, okay and then as you look at – and I understand when you talked earlier about your amount of business outside of the Gulf. As you look at 2011, kind of the crystal ball here for where work is most likely to be, is there a potential for you to move anything into Brazil, West Africa, kind of two markets you haven't really been in all that much historically? Something beyond I guess the Southeast Asian market where you've got the joint venture and you've worked a lot historically.

Bart you want to address that?

Yeah. West Africa we have been active this year. We had one of our RV support vessels working for (inaudible) Anadarko on the Jubilee project which is completed at work. So this year we spent eight months of time there. We also have a couple of RV’s working on a third party boat in the area. We see opportunities in West Africa to deploy one RV support vessel on a fulltime basis. So we are working towards securing that work. So we really haven’t been active in Brazil and at this moment we don’t – for our fleet of vessels we don’t see a lot of opportunity there. We still lag the North Sea where we have been very active with well ops and also with our trenching business option offshore Norway. There’s also a renewable energy market for offshore wind farms where we have been growing our market share from a trenching perspective. So that’s the color I can share.

Okay, thanks. And then the final question, the P&A work that will be done on the shelf fields, you mentioned an escrow number. Can you just give us an idea of how that flows through? Do we see that in CapEx or is it simply a balance sheet change?

It’s just a balance sheet change Roger. We have our P&A obligations book as a liability so it comes off as a liability. The field that Johnny was talking about that we have and it’s not reflected in our cash balance in escrow account for the South Marsh Island field and we have $35 million in escrow for that. So for the most part that’s just trade balance sheet accounts.

Okay, I mean so it's a cash impact but it's cash that's already set aside?

For that particular field yes and that’s probably our largest P&A obligation for next year, right Johnny?

Below just well P&A obligation.

Okay, so that's basically half of the P&A expenditure next year, right?

Probably not, less than that.

A little less than that, okay. All right, thank you.

Our next question from the line of Martin Malloy with Johnson Rice. You may proceed. Martin Malloy – Johnson Rice & Co: Good morning.

Morning Martin. Martin Malloy – Johnson Rice & Co: Could you talk a little bit about the impact on your DD&A rate in your listings cost from Phoenix coming online? Maybe if you could give in a dollar per bill year, dollar per MCFE?

Let me just talk about – Marty on Phoenix. Our DD&A rate is over $5 in amp. Our OpEx excluding the HP1, Johnny?

That’s about 700,000 a month so that’s going to add another $0.50 or so. That’s oil.

Yeah, the LOE is not big if you excluded the inter-company charge for the HP1 Marty.

And it’s an oil price. Martin Malloy – Johnson Rice & Co: And could you talk a little bit about the Caesar and going into dry dock or to get the thrusters put on I guess not dry dock, but is that going to fix the issues that you feel negatively impacted the vessel during the third quarter?

Yeah, this is Bart. Yeah really what’s caused the negative impact to me was the ramp up. I mean we are on the learning curve with this vessel. This vessel is a complicated offshore welding factory and so the main setback while – I mean you’ve got new welders, you’ve got the new marine and so the welding productivity was lower but its ramps up through the project and we have seen, continued to see that ramp up on the EOG project that we are doing at this moment offshore Trinidad where we still have around five days of fire play work left. So that’s a learning curve that we have seen. On the marine side of the vessel, there are a couple of things that we need to do to make the vessel a little more reliable. Again I mean when you start working in a vessel like this on this first big first and we were lucky to have 47 miles of 20 inch pipelay job so we found out – we identified the areas where we need to work on and that’s what we’ll be doing really for the second half November and December is to make it a more reliable vessel with higher productivity. So that’s our focus for the rest of the year. Martin Malloy – Johnson Rice & Co: Thank you.

Our next question is from the line of Philip Dodge from Tuohy Brothers Investments Research. You may proceed.

Thank you. Good morning everybody. You talked a little bit about the – looking forward on the Q4000, can you tell us your total intervention fleet including the sea well and the enhancer, how much is booked at this point for 2011?

As I mentioned, I mean the Q4000, we have backlog until the middle of the year. We see there’s quite some bidding activity. So we feel comfortable that next year we’ll be witnessing another year of good utilization. Same story applies to the Seawell and the well enhancer where we’ve got a couple of gaps in our schedule for the well enhancer for early 2011 but then especially because of the coiled tubing upgrades that’s going to be used to decommission several wells and fields in the North Sea. We think that’s going to help with the rates as Owen mentioned but also with the utilization of the vessel. So overall for the Seawell and the Well Enhancer we’re pretty positive for 2011 and then we’ve got the fourth vessel which is the Normand Clough which is a multi service vessel that can be used for well intervention. (Inaudible) well intervention project offshore Australia that we are bidding on. So we hope to secure that work. If not the vessel can also be used as an ESV, as in dock support vessel or as a light construction vessel and so together with our partner Clough are actively marketing that vessel in the Southeast Asia region. So overall on the well intervention side we’re pretty – we see that we have the backlog and we have the visibility.

Okay. Just related to that, if I knew this I’ve forgotten but how much is the uplift on the Enhancer for the coiled tubing capability?

I don’t have the number here right in front of me. Yeah I think it’s – I mean it depends also if you capitalize the cost of the marine crew etc during that period. But I think it was somewhere around 10 to 15 million.

Fine, thanks and then…

Sorry, that was the CapEx required.

Phil let us get back to you because I don’t think that we – we’ve got some contracts here in varying rates. Let us get back to you with the exact couple of number on the rate.

Alright Owen and just the final one on the Idle Iron, looking ahead with the new BO&E pronouncement, can you give us a metric on that of what you see the next two or three years in terms of well and platform shutdown say compared to 2010 as a base?

Yeah, I could talk a little about that. This is Johnny Edwards. We are in the process of putting together the final submission of the information to the BOE and it appears we have about 200 wells that will move forward in the schedule for a couple of years and so that – in 2011 most of those wells will be as I mentioned on South Marsh 130 and 2012 and ’13 we’ll have some more well accelerations. So we’re talking maybe – we’re not increasing our ARO, we’re just moving it forward in the 60 million or 50 to 60 million which part of that is covered by our South Marsh 130.

I was also thinking of the industry as a whole and how you might be able to participate in that with the Intrepid or some other…

Phil, this is Owen. I think the hockey stick projection of abandonment work driven by this latest NTL is perhaps a little overstated. I think the industry since Rita and Katrina have been working overtime to get caught up on the ARO issues. I know certainly we have but having said that, keep in mind that the NTL allows you three years to get this work done. So to the extent that you see producers out there that have a lot of work, I would not expect it to ramp up right away which gives us time to really consider putting the light intervention on the Intrepid and as you said the Intrepid is a very, very construction asset with a 400 ton crane. So there’s an awful lot of small salvage and P&A work that it would then be suited to do. That’s one of the mechanisms by which we’re making our plans so that we feel a little more comfortable about her full utilization next year.

Alright, that’s all I had. Thank you very much.

(Operator Instructions). Our next question from the line of Stephen Gengaro from Jefferies & Co. You may proceed. Stephen Gengaro – Jefferies & Co: Thank you. Good morning gentlemen. Can you give us sort of just an overall view of how you see sort of the contracting service market evolving over the next several quarters? I mean there’s been a lot of noise obviously with the drilling ban. You had a good quarter which was obviously boosted by some of the BP stuff, but how should we think about the pricing and utilization and how you think this thing plays out over the next couple of quarters?

I’ll take a shot. We’ve always told the investment community that the downstream construction market lags drilling by 12 to 24 months. If you take that as an assumption and drilling ceased in May and has not yet resumed really because of the permitting issues and assuming that permitting does start to move again by May, you’re looking at a one year hiatus from drilling which then should start to see impact sometime late in 2011 running through 2012. Now that’s on the construction side. Having said that though, when we saw the drilling moratorium put in place, pipeline permits also were frozen for some inexplicable reason. So there is a certain amount of backlog in the system waiting to be done which could carry the first part of 2011. But I do think that you’re going to see a slower Gulf of Mexico construction market late 2011 through 2012 but then that’s going to put more emphasis on production enhancement and well intervention as means of increasing production and capturing greater reserves. So all in all I guess that’s my read on it. Stephen Gengaro – Jefferies & Co: Okay, that’s helpful. That’s all I had. Thank you.

Our next question from the line of Vance Shaw with Credit Suisse. You may proceed.

Yes, good morning. Just want to ask a question on the portable converts and sort of what financing options you guys are taking a look at. I guess it's [portable] in December 2012, so you have some time, but I was wondering if you had any thoughts.

Well I mean I think we’ve got several options at this point. Number one we’re carrying fair amount of cash balances and we expect to build cash balances over the next few years. Number two, our credit facility is unused and that’s a $425 million facility. So we have plenty of liquidity in the event of a put by the holders and then there’s always the option of re-financing which I don’t think we want to consider today given that it’s over two years out and we’re in such a strong liquidity position. But I will say that’s one of the reasons why we’re building liquidity in the event that it is put, we’ll be prepared.

Super, thanks very much. And congratulations on a good quarter.

Thanks.

Our next question from the line of Sindry Survai from Orkla. You may proceed with your question. Sindry Survai – Orkla: Hi, good morning. This is [Sindry Survai] from Orkla in Oslo. Congratulations with good results. I just wondered if you could elaborate a little on the status on the divestment on the E&P portfolio especially in the light of to – at least to my surprise, there is already a few deals going on there, most recently there is the PXP deal announced in September and they also speak to their schedule of divesting their deep well assets by later this year. So, how is the outlook for your divestments?

I’ll take that. As Owen mentioned I think our process is still an ongoing process and we’re at a stage where we really don’t feel appropriate to comment on it. I think the Plains transaction was a particular transaction that had certain attributes that made it go that don’t apply to the rest of the industry. But overall I don’t think we’re in a position to comment right now. Sindry Survai – Orkla: Okay, thank you.

Our next question is from the line of Michael Marino from Stephens. You may proceed.

Morning. Quick question on the Normand Clough or the project there, when does that wrap up?

Yeah, this is Bart. We expect that we’ll wrap up at the end of this quarter.

Okay and everything to date is still going as planned?

I mean as I mentioned earlier we’ve had to – we booked a loss in the quarter so that’s an indication that it didn’t go exactly as per plan because we had some down low issues and we had some equipment problems. I mean we’re still trying to get some variation orders signed with the customer.

Which quarter is it? I guess the quarter to date, okay.

Yeah Michael just to clarify we’re taking a look out to the completion of the project in quarter four and booked the entire loss in quarter three. In other words, we projected out with a loss in the project is and the way accounting rules work you have to book it if you feel like you’re going to have a loss. So it’s all been absorbed in Q3.

Yes, okay. Just wanted to make sure. And then on the Caesar, will that be fully available for 2011 or does that dry dock spill into 2011?

We’ll have some downtime that – we’ll have some vessel downtime early 2011 but for the majority of the year the vessel will be available.

And I guess, remind us again, that vessel was very underutilized in 2010, so kind of year over year, the outlook is still pretty good for that vessel even in the current market environment.

Yes. She joined the fleet in; I think it was June of this year. We have been working her since early July and of course we have introduced these assets in a weak market. So hopefully the market will get stronger in the next couple of years.

Okay, thank you.

Maybe it’s fair to say that the Caesar is probably the singular asset that presents the greatest challenge to us next year on finding utilization on.

Our next question is from the line of Phyllis Camara from Pax World Fund. You may proceed.

Hi, thank you. You mentioned I think that you have got a backlog of $300 million so far. Normally in the past, how far out do you book jobs? And are you seeing – has it been just primarily because of the Gulf of Mexico that it's been different, if it is different? Or is this something that is typically – your jobs last for two months and three months and you have to – or continuously basically looking for work for your assets?

Yeah let me answer that question. I mean we normally have a role in six months backlog, that’s where we used to – with our assets. We’re not in an epic construction company where you’re having a three year backlog. We’re very comfortable with having three to six months backlog for our assets and so this is a number that we’re comfortable with.

And are you seeing – has bidding activity or people seeking bids for work, has that improved at all since the moratorium was lifted or are you still not seeing any activity at all for like six months out or 12 months out, something like that?

The lifting of the moratorium hasn’t had any impact on the business because there is some permanent moratorium at the moment. Nobody gets a permit to drill well. What Owen mentioned earlier is that there was also, I mean producers, operators had difficulty getting their pipeline permits and that was for projects that had been sanctioned before the pipelines that or pipe had been procured and we had pipe welded at our spool base ready to be installed but those operators didn’t get the permits. That has changed; they have been receiving the permits over the last couple of months. So that is work now that we have in our backlog, work that we will execute in the next sic months with Express and Intrepid in the Gulf of Mexico. But for the rest it really depends on these permits being issued and for the drilling to recommence.

And then in other parts of the world like in the North Sea, are you seeing bidding activity picking up or increasing or has it just held fairly stable throughout this whole thing?

Yeah that has been very stable. Of course there are the regulators around the world are looking what’s happening in the Gulf of Mexico. But we haven’t seen any impact on any projects or any drilling activity in other parts of the world.

Okay, great. Thank you.

Because we have no further questions at this time you may proceed with your presentation or closing remarks.

Hi everyone, this is Steven Powers. Just before we wrap up the call I’d like to provide you with my contact information. My direct line is 281-848-6644 and my email address is spowers@helixesg.com. Thanks everyone for joining us today. We thank you for your interest in Helix and very much appreciate your participation on today’s call. Operator Ladies and gentlemen that does conclude the conference call for today. We thank you for your participation and kindly ask that you please disconnect you line. Have a great day everyone.