Helmerich and Payne Inc (HP) 2013 Q4 法說會逐字稿

Good day everyone, and welcome to today's program. At this time, all participants are in a listen-only mode. Later, you'll have the opportunity to ask questions during the question and answer session.

(Operator Instructions)

Please note this call may be recorded. I will be standing by if you should need any assistance. It is now my pleasure to turn the conference over to Mr. Juan Pablo Tardio, Vice President and CFO. Please go ahead, sir.

Thank you, Justin. And welcome, everyone to Helmerich & Payne's conference call and webcast corresponding to the fourth quarter and fiscal year end of 2013. With us today are Hans Helmerich, Chairman and CEO, and John Lindsay, President and COO.

As usual, and as defined by the US Private Securities Litigation Reform Act of 1995, all forward-looking statements made during this call are based on current expectations and assumptions that are subject to risks and uncertainties as discussed in the Company's annual report on Form 10-K and quarterly reports on Form 10-Q. The Company's actual results may differ materially from those indicated or implied by such forward-looking statements.

We will also be making reference to certain non-GAAP financial measures, such as segment operating income and operating statistics. You may find the GAAP reconciliation comments and calculations on the last page of today's press release. I will now turn the call over to Hans Helmerich.

Thank you, Juan Pablo. Good morning. We are pleased to have posted all-time record earnings and revenues for the Company's year end results. It's a credit to our folks that they achieved this milestone during a year when the overall land drilling industry experienced activity declines and lower dayrates.

Looking back over the year, we estimate the industry delivered around 80 new AC drive rigs to the domestic market. These rigs predictably push the lower performing rigs to the sideline and now represent nearly 50% of rigs working today in unconventional basins. As this percentage continues to grow, we often receive questions from investors related to a narrative around a narrowing gap in terms of competitive overall rig offering in the land drilling space. The questions are fair and intuitively make sense. Some impending parity over an eight-year period should be expected. I say eight years because in 2005 our largest competitor announced a counter-offensive of a new build effort and we no longer had the AC drive rig market to ourselves. Not surprisingly, others fol owed and eventually, nearly 11 years after the Flex 3 AC drive debuted, every sizable land contractor, including a couple startups, were talking up the virtues of their AC rig offering.

In our thinking, after years of enjoying a first mover advantage, the greater challenge was to focus our efforts to establish a sustainable one. Our conviction was that the customer would differentiate and pay for outstanding field execution, improving efficiencies, and ongoing innovation and performance enhancements. Our people throughout the organization have delivered on each one of these and our financial results over the years have reflected their success as the FlexRig remains today the rig of choice.

Our 2013 fiscal-year performance provides an additional test case for how we are doing in an effort to stay ahead of the pack. Even in a challenging US land environment, we managed to increase our revenue days during fiscal 2013 by 3% as compared to 2012 fiscal year. While that may sound like a modest amount, it stands in contrast to our three largest peers experiencing a combined decline of over 15% during the same timeframe. More impressively, we delivered to shareholders this market share growth at daily cash margins that during fiscal 2013 were over 60% greater than the average combined cash margin of our top three competitors.

The resulting operating income in the segment for H&P was over three times larger than the average operating income of our top three competitors and significantly greater than the cumulative sum of all three. We have been able to combine our over 1,300 rig-years of experience with AC drive technology in the field with our ability to internally design and build what we believe is a better land rig for less money. The combination of these advantages has allowed the Company to deliver a 15% return on equity during fiscal 2013 as compared to our three largest peers, delivering returns that are close to half that mark, even excluding their write-offs and extraordinary expenses from these calculations.

While we have an abiding respect for the competitive nature of this work, the industry's challenges, and the daily rigor required from all of its players, all of us will continue to build new rigs and the whole industry will become safer and more efficient because operators will set the bar higher. But we doubt it will be a world of parity and sameness; differentiated performance still adds tangible value and will be rewarded accordingly.

We like our chances of continuing our success going forward. During the last few months, we've talked about encouraging signs in the market and we're pleased with the 13 total new build orders with long-term contracts, including those announced today that we've secured since October 1, the beginning of our 2014 fiscal year. This new book of business will achieve attractive financial returns, similar to the business model we've discussed in previous years. Generally, we target a range from the mid to upper teens, fully taxed annual ROIC with an after-tax contractual paybacks on a cash-on-cash basis of around 90% during typical three-year term contract.

Further, we are encouraged by ongoing conversations that we're currently having with customers for additional new build orders. Our plans today anticipate an ongoing cadence of two rigs per month for our 2014 fiscal year, but depending on market demand, we have flexibility to increase that production as we move ahead. We believe this approach will continue to reward our shareholders. And as I turn the call back to Juan Pablo, I'm very appreciative to all the people in the Company that contribute to our ongoing success. Juan Pablo?

Thank you, Hans. As announced earlier today, the Company reported a record level of $957 million of operating income for fiscal 2013. We also reported record levels of $737 million of net income and $3.4 billion of revenue for the fiscal year. Our capital expenditures totaled $809 million during fiscal 2013 and our corresponding estimate for fiscal 2014 is $850 million. The fiscal 2013 totals of $809 million was lower than expected as a result of underbudget deliveries of new rigs during 2013, along with the timing of some spending that shifted forward to fiscal 2014. Over half of the $850 million CapEx estimate for fiscal 2014 corresponds to our new build program, approximately one-third to maintenance CapEx and the remainder to tubulars and other projects.

Net cash provided by operating activities was approximately $1 billion during fiscal 2013. We expect at this point to be able to fully fund our fiscal 2014 CapEx provide as well as other scheduled commitments from existing cash and cash -- and from cash to be provided by operating activities during the fiscal year. Our confidence in our ability to do this is enhanced by the fact that we already have secured term contract commitments for an average of approximately 148 rigs during fiscal 2014 and 81 rigs during fiscal 2015. Approximately 90% of those rigs correspond to our US Land segment and provide the Company with the benefit of an average pricing level that, as described during our last conference call, is about 5% to 10% higher than current spot market pricing. Moreover, as some of our rigs that are under term contracts roll off these contracts, and as announced new builds are deployed under new term contracts, we expect the average pricing of remaining rigs that are currently under term contracts to slightly increase during fiscal 2014.

As reported in our consolidated financial statements, depreciation expense for fiscal 2013 was approximately $456 million. Given the continuing growth of our fleet, we expect our total annual depreciation expense to increase to approximately $500 million during fiscal 2014. General and administrative expenses are expected to slightly increase to approximately $130 million, and interest expense after capitalized interest is expected to increase, but remain under $10 million during the fiscal year. Our effective income tax rate for continuing operations during fiscal 2013 was reported at approximately 35.3%. We expect the effective tax rate for fiscal 2014 to be between 35% and 36%. Also similarly to fiscal 2013, we expect only a modest deferral of income taxes during fiscal 2014.

As it relates to our investment portfolio, the holdings remain unchanged compared to the prior quarter. I will now turn the call over to John, and after John's comments, we will open the call for questions.

Thank you, Juan Pablo, and good morning, everyone. While many industry observers are uncertain regarding a meaningful improvement in the US land rig count for the coming months, the industry's AC drive rig count has continued to march higher. In fact, over the past 12 months, the AC rig count is up approximately 120 rigs, while the combined FCR and mechanical rig count is down over 130 rigs.

The reason for this replacement cycle is well known. E&P companies are drilling a larger percentage of unconventional horizontal wells and the complexity factor of unconventional wells is much higher than a vertical well. In addition to greater well complexity, E&Ps are also expecting enhanced efficiencies from contractors. And that is the reason why advanced technology AC drive rigs and specifically the industry leader FlexRig should continue to grow market share. Customers continue to be results-oriented and there is a differentiation in performance across all rig types. We believe our results demonstrate that H&P is the best positioned to lead this replacement cycle. We are convinced we have the best personnel, technology, and systems that provide the reliability and efficiencies customers are looking for.

Now I will make a few comments regarding each of our operating segments and I'll begin with our US Land activity. The quarter was better than expected with approximately 245 average active rigs as a result of improving market conditions. An average of approximately 156 rigs were active under term contracts, while an average of approximately 89 rigs were active in the spot market. Average rig revenue per day also exceeded expectations during the quarter and increased to $29,058 a day. Early termination revenue accounted for approximately $740 per day in the fiscal quarter. Average rig expense per day was higher than expected and increased to $13,638 per day, primarily as a result of maintenance and supply expenses associated with multiple rig startups in addition to expenses associated with increased revenues. Average rig margin per day remained relatively flat at $15,420 for the fourth quarter.

We are pleased with the improvement in the US land market and customer demand for new FlexRigs. You may have read in our press release, we entered into agreements with three exploration and production companies to build and operate six additional FlexRigs in the US. Including the seven new builds announced on October 1, we have a total of 13 new FlexRigs contracted under multi-year term contracts so far in the first fiscal quarter. These rigs are expected to generate attractive economic returns for the Company.

A few more details on the 13 new builds contracted this quarter that wasn't included in the press release. We contracted the 13 rigs to five customers, a mix of long-term and new customers. The FlexRig models contracted included seven FlexRig 3s, five Flex 5s, and one FlexRig 4. By geographic basin, eight of the rigs are contracted for the Permian, two each for the Bakken and the Eagle Ford, and one for the Niobrara. 10 of the FlexRigs are equipped with hydraulic skid systems designed for efficient pad drilling. Currently, our active AC FlexRig fleet has approximately half of the rigs drilling on pads. Since 2006, we've drilled over 6,500 wells from over 1,500 pad locations with our hydraulic skid systems. 4 of the 13 contracted new builds have already started operations. Four more will begin operations in the first fiscal quarter, and the remaining five in the second quarter.

A few comments about how we see the US land new build market going forward. You may recall we didn't have any new build contracts to announce on our July call. This was mostly attributable to the fact that market dayrates and term contracts this summer wouldn't deliver the rates of returns we have historically achieved. So we were patient, waiting for the market to improve. Our ability to build FlexRigs at a reliable cadence and cost has allowed us to respond very quickly to the new build demand we've witnessed over the past 45 to 60 days. We've demonstrated the flexibility to build long-lead capital spares and convert those into new FlexRigs as needed to respond to customer demand and an improving outlook. Today, we have 255 active rigs, including 156 rigs under term contracts, and 99 operating in the spot market. All active rigs are AC drive FlexRigs.

Our US land fleet utilization today is 84%, with 48 idle rigs. However, our AC utilization has improved to 94% with only 15 idle AC drive rigs today. The three most active basins of activity for us are the Eagle Ford with 79 rigs, the Permian with 54 rigs, and the Bakken with 34 rigs. As evidenced by our new build announcements, our Permian activity has improved the most during 2013, up over 80% during the past 12 months. With the new build commitments we have today, we could have over 60 rigs running in the Permian in the second quarter of 2014 and there appears to be additional upside from there.

Looking at our US Land outlook for the first fiscal quarter of 2014, we expect revenue days to increase by approximately 3% as compared to the fourth fiscal quarter of 2013. We expect the average rig revenue per day to be flat to slightly down and average rig expense per day at roughly $13,000 per day, plus or minus a few percentage points as compared to the fourth quarter. We are pleased with the direction of the US land market today, as dayrates have strengthened in both the spot market and term contracts. In addition to experiencing an uptick in new build demand, our idle AC rig count is at the lowest level since the third fiscal quarter of 2012. You will recall that was just ahead of the industry activity pullback in the fall last year. Another indication we are seeing of market strength today; of our 15 idle AC rigs, 9 are already committed for upcoming work.

Now, a few comments regarding the Offshore segment results for the fourth fiscal quarter. Revenue days were in line with our expectations. However, our operating income had a shortfall as a result of a $6.4 million charge related to events the Company discovered in 2010. Excluding that charge, margin per day would have increased by $1,569 sequentially to $26,677 a day. Now, looking at the outlook for our Offshore segment. As of today, the segment has eight rigs active and one rig stacked. We expect eight rigs to remain active throughout the first fiscal quarter of 2014. As compared to the prior quarter, we expect Offshore revenue days to be flat and margins to be approximately $25,000 per day.

Turning to our International Land segment, where operating income of $13.9 million exceeded expectations as a result of better than expected margins and higher revenue days. Today, the International Land segment has 23 rigs working, of which 13 are AC drive FlexRigs. Of the active rigs to date, eight are in Argentina, five each in Colombia and Ecuador, two each in Bahrain and the UAE, and one in Tunisia. A total of six rigs are idle in the following countries. Two in Colombia, and one in Argentina, Bahrain, Tunisia, and Ecuador. As a result of these activity levels, we expect International Land revenue days to decline by approximately 10% and margins should be flat quarter to quarter. So while the quarterly rig activity is softer than expected, we remain bullish long-term on international growth opportunities. We believe the driver of that growth will occur when unconventional resource plays gain more traction globally. With H&P's 50-plus years of international experience, coupled with FlexRig's efficiency and expertise, we believe larger scale customer adoption of our service offering in international markets is likely.

Now, in closing, even in the face of a challenging rig market like we've experienced over the past year, we've been able to grow our market share and deliver the highest levels of rig efficiencies and safety performance in the industry. I would like to thank all of our field personnel, office staff, and Management teams for an outstanding 2013 fiscal year. All of these achievements that have been accomplished are possible because of our people's commitment to the Company's vision of providing safe, efficient, and cost effective performance for our customers. That completes my operating segment remarks. Now I'll turn the call back to Juan Pablo.

Thank you, John. And Justin, we will now open the call for questions.

(Operator Instructions)

We'll take our first question from Robin Shoemaker. Please go ahead, your line is open.

Thank you.

One -- my question, John, would be that, in terms of the strength you're seeing in spot and term prices for FlexRigs, I guess we're seeing that overall flattish rig count. And so what would you attribute the strength you're seeing in spot and term rates today? Is it in anticipation of stronger demand? So what's your outlook for the overall rig count?

Okay, Robin.

Well overall and historically in this business, we've focused our attention on the industry -- the overall industry rig count. It was a much better barometer, I think, of demand than what it is today. And Hans and I both have tried to address that. And when you consider the premium end of the market, if you consider the AC drive section of the market, and if you look at the overall utilization of AC rigs in US land, even though there's between 70 and 80 rigs stacked today, the utilization is still 90% or so.

So there's a pretty clear level of pricing power that's there, as evidenced by new build announcements. I think there's an opportunity, and we've seen over the last, oh, 60 days or so -- 90 days, 60 or 90 days or so -- we've seen more spot market price firm, and we've actually seen a little bit of pricing power.

So I think that's why we see it. And again, when you look at the overall rig count trending sideways, it's hard to see that there would be pricing power. But I think if you look at the premium end of the market, that's where we see the pricing power.

Right. Okay. Understood.

So now, in terms of your success in holding down or actually possibly lowering operating costs of rigs, is this tied into the greater prevalence of pad-type drilling? Less downtime, more efficient utilization related to pad drilling, or other factors?

I want to make certain I understand your question. You're talking about our costs over the last 12 months?

Yes. Just the holding down of cost escalation on a daily operating per-rig basis.

Well, we really haven't considered the pad drilling aspect of, necessarily, at least what we've seen, on our cost controls. I would say our cost controls are more a function of our systems and our processes that we've had in place or that we have in place and that we've improved, and our people's focus on that. Because whether we're drilling on pads or whether we're drilling on single-well locations, the fact is, the rigs are working much harder today than a rig has ever worked.

I mean, the lateral length, the hydraulic horsepower requirements, the cycle times -- sure, I think there could be an argument to be made that if you're moving the rig less frequently with trucks, there's going to be some savings in cost. But I think, at least for us -- I'm speaking for H&P -- I think our cost effectiveness has been more a function of our process improvement and our uniform fleet. The fact that all we're working are Flex 3s, 4s, and 5s -- I think that's really what drives our efficiencies.

Right, okay. All right. Well, thanks a lot, John.

And we'll take our next question from Jim Wicklund from Credit Suisse. Go ahead. Your line is open.

Good morning, guys. Hans, John, Juan Pablo, and your entire Company -- I don't usually do this, but you guys are a class act. And congratulations on setting a record in a year where nobody would have expected it. So from the industry perspective, you guys are a class act. Good job.

Well, thanks, Jim.

My question, if I could -- you guys recently won a platform contract with Shell. Can you tell us about that?

I'm going to have John tell you about it. I wanted you to pause after that comment and just let us kind of enjoy that a little bit. (laughter)

Bask a little bit. Bask.

That was nice, Jim. Thanks.

Jim I know --

-- from everybody else for saying it so I thought I would jump into my question.

Well, thank you, and I fell out of my chair when you said it, so I'm trying to recover. What was your question again?

You guys recently won a platform contract, I understand, with Shell. An offshore platform contract, is that right? Did I hear this right?

Well, Jim, it's probably a pretty solid rumor, but at this stage of the game, we can't talk about it much. We'll have more clarity on our next call in January.

Typically, how big are the platform contract jobs that you do? What size horsepower rigs are those?

They are 3,000-horsepower is most of what we're looking at.

And can you just give us a ballpark idea generally of what 3,000-horsepower platform rig dayrates are?

Well--

Just broadly.

Yes, it's in line with what we have. It's probably high $50,000s, low $60,000 day range.

Okay. That will do. Okay. (multiple speakers) -- too much. Thank you much. Good job.

Okay. Thank you, Jim.

Thanks, Jim.

And we'll take our next question from Ryan Fitzgibbon from Global Hunter. Please go ahead, your line is open.

Good morning, guys. Congrats on the new builds.

Thank you.

Thank you.

First one for me is really on your contracting strategy at this point. Your spot exposure has gone up a bit. I imagine that coincides with better pricing in the spot market. You talked about how you expect your spot exposure to trend going into 2014, given, I would expect, some of the operators are looking to lock in rigs, first. And then second, can you quantify how spot market rates actually change quarter on quarter for you guys?

Ryan, this is John. I'll talk a little bit about the spot market. I'm going to have Juan Pablo address your last part of your question.

You're right. Our percentage of spot market rigs is higher than it has been trending over the last couple of quarters. I would expect to see more of the spot market, some of the spot market rigs roll into term contracts.

As far as a strategy, we're really going to do what the customers' demands are. I mean, if they are wanting to enter into term contracts and we're going to be willing to do that, obviously if you look at it historically, we've been satisfied in that 50/50 range over the last year or so. I think we've been higher, where it's been two-thirds and one-third. So we're going to be comfortable in that 50% to 65% range. We're not really concerned about it one way or the other. But I do think with the market tightening a little bit, I would expect to see more of the spot market rigs going into term.

This is Juan Pablo.

To your question regarding spot market rates and how those have evolved -- as you know, at the beginning of the year we saw a little softness there and we had a slight decline since then. June quarter to September quarter, we experienced a very slight decline in pricing and average revenue per day for rig in the spot market. Going forward, we hope that, that changes.

Our expectation is for spot pricing in general to be slightly up, or flat to slightly up. Now there are other moving variables as well, in terms of where those rigs might be working and what kind of pricing structure and cost structure there might be in different regions. But in general, we expect a positive movement in terms of spot pricing going forward.

Okay. Juan Pablo, I believe in your opening remarks, you said 5% to 10% discrepancy there. Safe to assume, given it was a 12% discrepancy in the June quarter is at the high end of the 5% to 10% range right now?

Yes, I wouldn't describe it as a discrepancy. I would just describe it as the difference between the pricing of our rigs that are under term contracts and the pricing of our rigs that are in the spot market. And so as we see what we had in terms of results for the September quarter, it's fair to describe that the difference between those two categories is approximately 5% to 10%.

As you can imagine, and as I think we've mentioned in the past, there are other considerations related to the mix of where the rigs are working and what type of rigs are under term and what type of rigs are in the spot market and so forth. But I don't want to get into much of that. It's way too many things that move, many variables that move at the same time. But in general terms, hopefully again what we see is, going forward that gap in terms of pricing -- apples to apples pricing, that is -- start to reduce into fiscal 2014.

Got it. Makes sense.

Second question for me is on international bid opportunities. I believe on last quarter's call, you mentioned there's a couple tenders out in the Middle East you were looking at. Just hoping to get some color as to how that progressed throughout the quarter and maybe what our outlook is for 2014 on new build opportunities internationally.

Ryan, we're still participating in tenders, both in South America and in the Middle East. We don't have anything to announce at this stage. Our hope is that we'll be successful on some of those tenders. As compared to the US market, international market moves quite a bit slower. But we're hopeful that we'll have something.

It's hard to say if it's going to be in the first part of 2014. We would have all believed that our international activity would be higher than it is right now, with the success we've had with FlexRigs working internationally from an efficiency and safety perspective. But that's really all we have to update right now. We're upbeat about it. It's just moving fairly slow.

Thanks, guys.

(Operator Instructions)

And we'll take our next question from Brad Handler from Jefferies Securities. Please go ahead. Your line is open.

Thanks. Good morning, guys.

Good morning.

Maybe I'll start with dayrates also; and I admit it, I ask this question and probably it's going to feel to you like it's more to do about very small moves than anything else. But if you laid out maybe an academic mathematical process for us a quarter or two ago around rates, given your commentary today and given some of the positive stepping, some of the positive hints that you're giving about rates, does that profile for how the average dayrate through 2014 progresses? Does that change? Does it become a little less flat to down modestly and a little more flat, say? For example, just trying to pick up on where you're taking us.

Thank you, Brad. This is Juan Pablo.

You're exactly right. It was a comment based on a theoretical scenario and academic-type scenario. What happens is, everything else remains more or less equal and spot pricing remains flat through fiscal 2014. What might that do to the total average revenue per day in the US Land segment? And the answer to that was, well, it probably would impact it so that we would see a reduction of 1% to 2%, or a couple of percentage points.

I think that theoretical scenario is still true today. Of course we could lay out a different scenario, and that scenario being what happens if we have spot pricing increase 5% to 10% to match what we have rigs under term contract priced at. And how would that impact the total average revenue per day for fiscal 2014? And I think that the -- again, theoretical -- answer to that scenario would be that we would see the opposite. We would see an increase of 1% to 2% in terms of our average revenue per day.

Okay.

Does that address your question, Brad?

It does. It looks like you thought about that question, so that's helpful. Let me shift gears, please.

There was something that I am unfamiliar with and I would love to understand it better. Although John didn't mention it in his prepared comments, you mentioned that the revenue per day in the fiscal fourth quarter was positively impacted by customer-requested delivery delay fees.

So I don't know if that wound up not being a big part of it, since John didn't mention it. But to the degree that it is, I would like to understand that a little bit better. What are the dynamics there? For example, I assume the contract start is pushed out. That sounds like the purpose. Is it the same term? Does the rate get impacted? How prevalent is this in your contracts? Et cetera?

Well, Brad, this is John.

It's not very prevalent in terms of a percentage. As we think back, really since 2008, 2009, we've had examples where customers have delayed deliveries. It doesn't happen very frequently. There's some compensation associated with the delay.

And that's really -- I didn't feel like it was enough of a percentage of what we do to address it in the detailed comments. I thought the press release handled it very well. So it's not a very prevalent situation, particularly in a market like this, where it continues to be fairly strong.

Okay. I suppose that addresses it; but before I just drop it all together, is there any hint in seeing it of whether it's a function of a customer seeing even greater efficiencies and therefore needing a little less rig? Is there a way to generalize some of the driver behind what you've seen here? Or perhaps you could attribute it to something else?

I don't know the specifics. I don't think it's necessarily a function of efficiencies in having too many rigs. I guess it could be as it relates to a budget. But again, it's part of a budget function that the customer has, if they want to delay activity. And this is a US Land and an international situation. It's not just US Land.

Okay. All right. Helpful color, thanks. I'll turn it back.

Thanks, Brad.

And we'll take our next question from Byron Pope from Tudor Pickering. Please go ahead. Your line is open.

Good morning, guys.

Good morning.

Just one question for me -- John, I was struck by your commentary about your being down to 15 idle AC rigs. Just given that it seems as though most of this calendar year you have been bouncing around between 18 and 20 idle AC rigs, and so the comment I was struck by was when you mentioned 9 of those 15 idle AC rigs are already committed for work.

So I was just hoping you could speak to the progression of when those 9 rigs go to work. Because it almost feels to me like you're getting a sense from the E&P operators that once we get into Q1 of next year, your utilization is going to be fairly tight. I was just wondering if you could comment a little and provide some incremental color on when those rigs go back to work.

Well, Byron, that is what we were trying to express. You're right.

It's been over, well, between 18 and 22 rigs since the third quarter call in 2012. And again, we've made the point on previous calls, it's not the same 20 rigs. There's a churn that's going on. And I think on the last call we had commented that it appeared that there were less rigs -- and maybe it wasn't on the last call; maybe it was in some of the conferences in September and October. But there's just less customers giving rigs back to us. We're still putting rigs to work, but there's less rigs that are getting released.

I think that's what we're seeing. And so clearly, the demand has improved. We're seeing fewer customers releasing rigs. They are hanging on to their high-performing AC rigs, and we're in a position where we just have a handful of AC rigs that are available as existing rigs in our spot market. So we see that as a positive. And again, I think it could speak to a little bit more pricing power for us -- for us and others in the industry.

Okay, and I think the way you've characterized it before is, idle rigs that you've had have been spread across basins. So is it fair to think that this subtle shift in the mentality among E&P operators is fairly broad across basins?

Yes, we've been pleased. I mean, overall, we've had some nice contracting strength in really all of the basins.

Clearly, Permian is a lot more active than any other basin. But yes, we've been pleased with getting nice response in all of them. So we're seeing rigs in all the basins going back to work.

Okay. Great. Thanks, guys. I appreciate it.

Thank you.

Thanks, Byron.

Thank you, Byron.

And we'll take our next question from Doug Becker from Bank of America. Please go ahead. Your line is open.

Thanks.

John, I wanted to hone in a little bit more on the Permian demand. You indicated H&P could be close to 60 by the second quarter. With upside to that number, what kind of upside are we talking about, particularly in the context of maybe infrastructure constraints and still a very low level of pad drilling taking place in that basin?

You're right on the pad drilling, Doug. I think there's less than 20% of the wells out there are being drilled off of pad. So there's a lot of opportunity to improve. And the 60 number that we put out there is really just taking the new builds that are out there. We're having to assume that the current rigs are going to continue to work. We're obviously assuming that oil prices remain strong, and we don't have a pullback anywhere. So yes, we could see it at 60.

But what you're seeing in the Permian at the same time is, the overall Permian rig count's not growing. You've got your vertical rigs going down, your lower end rigs being stacked. And so the question is, much like the overall industry rig count, what kind of a trade-out ratio happens? What kind of a replacement ratio happens? Is it one-for-one or is it one-for-one and a half, whatever it may be. It's difficult to really predict where the rig count is going. I think it's going to be driven largely by the unconventionals and the horizontal rig count.

So if I understand what you're saying, not expecting a big increase in the overall rig count. Just the continuation of that shift to the horizontal and presumably H&P taking some additional market share in that context?

Yes, I don't see how -- I'm not aware at least that the vertical rig count or the lower end of the market in the Permian is going to do anything but -- the Permian, the low end of the rig count's going to continue to reduce, best I can tell. And customers are going to want to drill more horizontal wells, and a lot of the rigs out there just aren't qualified, capable of doing that type of work.

Got it. And then Hans -- what would you need to see to accelerate the cadence of two new builds per month? Obviously an improving market, but do you need to actually have a contract in hand? Or would you build a little bit in anticipation of that, given just the philosophy and flexibility of using that equipment ultimately for spares if a contract doesn't materialize?

I think the two rig per month cadence that we have now, and we're talking about extending through the rest of our 2014 fiscal year, is a good baseline. And so I don't think we would reach for additional cadence without market demand and a demand pull-through. So we like the conversations we're having today and some of the things we've talked about on the call. So I think that's the approach we're taking.

Understood. Thank you very much.

Thank you.

(Operator Instructions)

We'll take our next question from Mike Breen with Och-Ziff Capital Management. Please go ahead. Your line is open.

Great quarter, congratulations.

Just out of curiosity, how many customers are you working for now in the US versus 6 months ago or 12 months ago?

Mike, I want to say our total customer count is right at 50. I think that's right, in the US. And that's probably up 10 customers over the last year.

We've added quite a few new customers. We've had quite a few new customers in the Permian and the Eagle Ford; and several of those are smaller customers, smaller E&P, so that's been encouraging. As you know, a large percentage of our customers are majors and large independents. So it's been nice to do more work for some of the smaller independents.

Okay, and then one last question. Is your profit margin pretty much the same basin by basin, or is there significant difference anywhere?

Mike this is Juan Pablo.

In general, what happens is that we obtain the same type of returns for new builds that go to different regions, but the difference might be related to what type of rigs are used in different regions. If we have, for example, a larger rig like a FlexRig 5, we're going to have a larger dayrate and a larger margin corresponding to that rig in order to yield the same level of returns that we expect, as Hans mentioned, given the higher level of investment. For areas where the need is for much a smaller rig, the margins might be smaller in terms of cash margins. But in general, again, based on returns, I think they are equivalent, generally speaking.

Okay, but one rig in one basin would be about the same as a similar rig in other basins?

Yes, sir.

Okay. Thanks.

And we'll take our next question from Brad Handler from Jefferies. Please go ahead. Your line is open.

Thanks for letting me back on.

Juan Pablo, maybe directed at you, a question about the CapEx. Are you comfortable splitting out how much capital is carrying into fiscal 2014 from fiscal 2013 that's driving the lower than expected CapEx number for fiscal 2013?

In general terms, I'll be glad to do that. We have an $890 million estimate for fiscal 2013 and the result was $809 million, as I mentioned earlier. And most of the difference between those numbers resulted from the shift in spending from one fiscal year to the other.

All right.

At least I gave you some, some--

I suppose it's more than half, right? Okay. If I think about it, I would love to -- go ahead.

As I mentioned also earlier, most of the rest was related to being under budget in terms of the construction of our new builds, which again, was a great achievement internally and we thank our people involved in the process for that.

Understand. And I suppose in fairness, that's what I was trying to get after. And then thinking about that structurally going forward, so in a way, I felt like I was handing you an opportunity to describe that for us to some degree. But can I think about -- I don't know; I guess I'll press you -- can I think about three-quarters of that shift being a pushing things back into fiscal 2014? Am I in the right ball park?

Yes, as I mentioned, I would prefer not to be that detailed in responding to that.

Okay. Fair enough. Thank you. I'll turn it back.

(Operator Instructions)

And there appears to be no further questions.

Okay. Well, thank you very much. And good day to everybody.

Thank you.

And this does conclude today's program. You may now disconnect, and have a good day.