As a reminder, this conference call is being recorded. I would now like to introduce your host for today's conference, Kelly Youngblood. Sir, you may begin.
Good morning, and welcome to the Halliburton's Q2 2013 conference call. Today's call is being webcast and a replay will be available on Halliburton's website for 7 days. The press release announcing the 2nd quarter results is also available on the Halliburton website. Joining me today are Dave Lazar, CEO Jeff Miller, COO and Mark McCollum, CFO Tim Probert, President of Strategy and Corporate Development will also be available today for follow-up calls. I would like to remind our audience that some of today's comments may include forward looking statements reflecting Halliburton's views about future events and their potential impact on performance.
These matters involve risks and uncertainties that could impact operations and financial results and cause our actual results to materially differ from our forward looking statements. These risks are discussed in Halliburton's Form 10 ks for the year ended December 31, 2012, Form 10 Q for the quarter ended March 31, 2013 and the recent current reports on Form 8 ks. We will welcome questions after we complete our prepared remarks. We ask that you please limit yourself to one question and one related follow-up to allow more time for others who have questions. Now, I'll turn the call over to Dave.
Thank you, Kelly, and good morning to everyone. Overall, I'm pleased with our 2nd quarter results. Total company revenue of $7,300,000,000 was a record quarter for Halliburton and operating income was over $1,000,000,000 We achieved record revenues this quarter in our Bayroids, cementing, completion tools, multi chem and testing product lines. From an operating income perspective, Bayroid testing and artificial lift also set new records. Turning to the geographies.
Our international operations grew 8% sequentially, which
is at the top
of our peer group. This growth came from record revenues in both of our Eastern Hemisphere regions. Compared to our 2 primary competitors, we have delivered leading year over year international revenue growth for the last 5 quarters. Also notable for the quarter, our international revenue comprised almost half of our total company revenue, which clearly demonstrates the success in our ongoing strategy to grow our international business and balance our geographic mix. So clearly, we are not just a North America pressure pumping company.
Our Eastern Hemisphere played out as we expected. Revenue was up 11% sequentially and operating income was up 23%. I want to specifically highlight our Middle East Asia region, which had an outstanding revenue growth of 20% and operating income growth of 43% relative to the Q2 of last year. This is a very exciting market for Halliburton today and we expect our Middle East Asia region to be the highest growth one that we have led by Saudi Arabia, Iraq and all of Asia. For the year, we still fully expect Eastern Hemisphere margins to average in the upper teens with year over year revenue growth in the mid teens.
With pricing improvement opportunities in the Eastern Hemisphere continuing to be somewhat elusive, our current operating bias is toward improving our utilization and efficiency as we address the increased spend from our customers. Jeff will discuss the weaker than expected Latin America performance and the Mexico integrated project market in greater detail. But I want to be clear on one thing. We feel confident that revenue and margins in Latin America will improve in the second half of the year. We expect margins to improve in the Q3 and approach the mid teens level and expect full year margins to be approximately the same.
In summary, our international outlook has not changed. We expect consistently solid year over year growth in several key markets. Although there is still uncertainty around Egypt, Libya and Northern Mexico activity for the near term, our deepwater share gains coupled with increased rig count in Saudi Arabia and an anticipated rebound in Latin America during the second half provide us confidence that we will continue to outperform on a relative basis to our peers. North America also delivered results as we expected and I am pleased with the quarter. Revenue was up 3% despite a sluggish U.
S. Land rig count and a 71% lower Canadian rig count. We also saw 120 basis points sequential improvement in our margins to 17.5%. We are now expecting the rig count to remain relatively flat for the remainder of the year as we observe a meaningful switch to multi well pad activity among our customer base. We believe these incremental drilling efficiency gains will provide for higher service intensity.
We currently estimate that pad drilling represents as much as 50% of the activity across key U. S. Basins and will continue to tick higher. As an example, we've seen the Eagle Ford grow from less than 40% pad activity last year to over 60% today. Ultimately, we believe this efficiency trend bodes very well for us in the long run as our scale and expertise allows us to lead the industry in executing factory type operations.
And despite issues around capacity, utilization and pricing for the balance of the year, we do expect North American margins to continue to improve. We believe we customer plan revisions and their impact on activity in the Q4. However, we believe that current commodity prices make budget reloading a more compelling option for our customers, which could help mitigate the risk to a 4th quarter slowdown. I am optimistic about Halliburton's relative performance for the remainder of the year and our ability to grow our North America margins and continue to realize revenue and margin expansion in our international business. Our strategy is intact and working well and we intend to stay the course.
We will continue to drive toward expanding our global portfolio in deepwater, mature fields and unconventionals. We have been and will continue to be focused on delivering best in class returns. We bought back $1,000,000,000 of shares in the Q2 and today announced an additional repurchase authorization
to a total
of $5,000,000,000 These actions reflect our growing confidence in the strength of our business outlook and our ability to not only increase our buybacks, but our dividends, while leaving room for any capital spending or additional acquisitions we may want to do. Now let me turn the call over to Jeff and he'll provide some additional operating detail.
Thanks, Dave, and good morning, everyone. Let me begin with an overview of our 2nd quarter results. The Eastern Hemisphere had solid sequential improvement compared to the Q1 of 2013 with revenue growth of 11% and operating income growth of 23%. The improvement was led by seasonal recoveries in Norway and Russia along with improved activity levels in Angola and across all of Asia. In the Middle East Asia region, compared to the Q1, revenue and operating income increased 12% and 17% respectively.
The growth was driven by higher stimulation, wireline and fluids activity in Malaysia, increased drilling and stimulation activity in China and improved profitability in Iraq. The Middle East Asia is a high growth region for us. And Malaysia is a great example, where revenue grew 40% year over year and profit more than doubled, driven by strategic offshore wins. We continue to build on this success in the Q2, displacing a major competitor to provide offshore cementing services and in addition winning a series of fluids contracts in Malaysia with an aggregate estimated value in excess of $500,000,000 over the next 4 years. Additionally, continuing our growth in Saudi Arabia, in the Q2 we were awarded a 3 year lump sum turnkey project to provide reentry services in an existing field.
This strategic win comes in addition to a recently expanded award for our multi rig turnkey project in the Kingdom. Turning to Europe Africa CIS. Relative to the Q1, revenue and operating income increased 9% and 33% respectively. The improvement was driven by higher fluids and cementing activity in Russia, increased stimulation fluids and completion tools activity in Norway and higher drilling and completions activity in Angola. A highlight of note in the region, during the Q2, our Veroa product line partnered with Cobalt International Energy to transfer our supersaturated riser viscosity fluid technology from the Gulf of Mexico to deepwater Angola.
This fluid is a key enabler of riser with deepwater drilling and we believe this technology will be instrumental to the future success of Angola's new sub salt drilling projects. Within Europe Africa CIS region, we also have been successful in executing several strategic integrated projects. Let me give you a few examples now. In Russia, we saw early success with our Yogyogin integrated tight oil project. The project began earlier this year and by applying unconventional multistage completion techniques to the mature field, production has already materially exceeded targets, leading to substantially increased activity in this field.
Norway recently completed the first phase of an integrated multi well project. Based on our success in delivering services and accelerating the production cycle, our contract has been renewed through 2015 and was expanded to include 2 additional fields. And finally, in the Dana sector of the North Sea, we were recently awarded a 5 year multi product line contract with an estimated value of over $100,000,000 to provide services on a high pressure, high temperature development. This award was based on our proven track record of delivering integrated services in the Scandinavian market and our recognized expertise with HPHT Services. All three of these projects are good examples of how we collaborate internally and with our customers to drive value into a project both for the operator and for Halliburton.
Overall, our Eastern Hemisphere performance has been impressive. If we look back to this year last this time last year, we've grown revenue by 16% and operating income by 22%. In Latin America, we had a disappointing start to the year. Revenues compared to the Q1 and operating income was down 7% as a result of reduced drilling activity in North Mexico, increased mobilization costs in both Brazil and Mexico and lower vessel activity offshore Mexico. But moving into the second half of the year, we're confident that we will see an uptick in Latin American financial results.
Let me touch on a few of the key drivers now. In Colombia, we see second half levels improving as our customers resolve some of the recent permitting delays. In Brazil, during the Q3, we will complete mobilization of our directional drilling contract and expect to transition to our new market share in the Q4. And finally, in Mexico, we expect to see the largest improvement. In the 3rd quarter, we're confident that we will secure contract approvals related to our consulting and software services and see increased utilization of our stimulation vessels.
We also expect to have finished mobilization of equipment for a recent offshore intervention services contract. We anticipate the North Mexico activity will continue to be an issue for the region in 2013. However, I'm pleased to announce that we were recently awarded the Hamaca block by Pemex in the latest round of incentivized projects. Scheduled to begin in early 2014, this estimated $1,200,000,000 project is for a multiyear asset management contract in the Chekamapec Basin. This most recent round of incentivized contracts differs from the previous round and that it provides 100% cost recovery for our services during the first phase of the project.
We expect returns for this project to be generated from our own service revenues and to be accretive to our overall business. We were very selective in targeting the Jemapa block. In fact, it was the only one we bid on, because we believe that this project will generate robust returns at a lower level of risk and that our experience in the nearby Remalina laboratory gives us a technical advantage in delivering timely productive wells. We're also currently evaluating a pipeline of large integrated projects in Mexico valued at an estimated $8,000,000,000 We expect this work will be awarded towards the end of the year. With the combination of these integrated projects and the Jemapa project, we're excited about 2014 and beyond for Mexico.
Let me give you a few other Latin American highlights for the quarter. In Brazil, we inaugurated our technology center in Rio de Janeiro, where Halliburton personnel will collaborate with operators and the country's leading university and a global center of expertise for both deepwater and mature fields. Further, in the ultra deep pre salt market at Brazil, Halliburton successfully performed the deepest wireline fluid sampling and rotary sidewall coring job ever undertaken. Samples were retrieved from depths of over 22,000 feet, helping our customer identify the most productive zones of this exploration well. We also see opportunity in the offshore Mexico market where we recently displaced a major competitor to provide open hole logging on a deepwater well based on our reservoir characterization portfolio, including our GEM mineralogical tool and our RDT formation tester with fluid identification.
Now moving to North America. Revenue was sequentially up 3% and operating income was up 10% driven by increased U. S. Land seasonal activity in Canada. Consistent with the Q1, approximately 85% of our crews are under long term contracts and about 3 quarters are working 24 hour operations.
In spite of a relatively flat sequential U. S. Rig count, drilling efficiencies in the trend towards multi well pads are driving a more robust well count. Additionally, in some cases, we're seeing operators increasing the number of stages on horizontal wells performing as many as 40 stages per laterals in the Marcellus in certain examples. It's our view that the resulting increased well count and stage count could absorb a meaningful percentage of the excess horsepower and help drive service intensity across all product lines.
Although we believe excess pressure pumping capacity has diminished since the Q1 due to rising demand, there is still an oversupply in the market. As a result, we anticipate that pricing pressure will persist to some degree across many North American basins in 2013. Additionally, as we gauge the utilization of our equipment on a 20 fourseven basis, we see a significant opportunity to improve and drive the white space. By that I mean the downtime out of the schedule. In this environment, we believe it's more important than ever to be aligned with the most efficient customers where we can create the most value for our customers and deliver the best returns for Halliburton.
We are continuing to execute our strategy around surface efficiencies, subsurface technology and custom chemistry, delivering differentiated services that generate superior returns over the long term. As part of this larger strategy, Track of the Future and BattleRev are really the platforms that enable surface efficiency. And we expect to see increased performance at the wellhead as we incorporate these tools into our processes. Valor Red effectively applies new processes and technologies to standardize and automate integrated workflows across our product lines, driving improved efficiency across our North American service delivery organization. Although there are some associated cost savings, this initiative is primarily directed at improving working capital and cash flow.
We're targeting a 50% reduction in days to bill our customers and we expect these tools to also be able to help manage inventory levels, reduce overtime and optimize well site deliveries. As an example, we've already seen a 15% to 20% reduction in costs around freight and standby charges. We anticipate the Battle Red rollout will be completed in the Q1 of 2014. Next is our Frac of the Future program, which is designed to reduce capital and operational costs at the well site. Early data indicates our Q10 pumps are running 2 to 3 times longer than existing Halliburton pumps and 5 to 6 times longer than the industry standard before requiring maintenance, which we anticipate will reduce our fleet maintenance expense by up to 30%.
This efficiency also allows us to reduce the equipment needed on location by an average of 25%, decreasing the capital required to deliver frac fleet and reducing labor and fuel costs. Specific to labor, through process automation and reduced vehicle counts on the job site, over the last 2 years, we have reduced our crew sizes by close to 30% and believe our crews on location are currently streamlined. When we look at what we're able to deliver on a stage per headcount basis, we've seen a 40% rise in executional efficiency over the same time period. By the end of this year, we anticipate that close to 20% of our fleet will be converted to frac of the future. The rate at which we deploy going forward will be dependent on 3 factors: North American natural gas activity, the growth of international unconventionals and our requirement to replace older equipment.
We believe our manufacturing capability is a strategic advantage, allowing us to manage deployment and quickly take advantage of changing market conditions. Assuming a consistent build schedule of new equipment, we expect to reach the 50% mark on frac of the future deployment during 2015. We believe these strategic initiatives will deliver material differentiation and provide a sustainable competitive advantage to Halliburton for years to come. Turning to the Gulf of Mexico. Revenue was impacted by BOP certification related issues that have delayed several of our large completions to the back part of the year.
For the remainder of the year, we expect revenue and profit will average higher than the first half as deepwater rigs arrive and more rigs move to development and completions. We're optimistic about the Gulf of Mexico deepwater market and are excited about our competitive position in the lower tertiary, the market that we expect to nearly double in 2014. We continuously look for ways to better manage cost structure in the organization. As we migrate towards more efficient differentiated service platforms such as Battle Red and the frac of the future, it will have an impact on support and operational headcount as well as equipment and inventory requirements. We expect to complete an evaluation of these areas and to take action on them in the Q3, which will result in severance and other charges during the quarter.
We'll be identifying these separately in our Q3 results. So to summarize North America, we're forecasting the rig count to remain stable for the year, but believe that activity levels can improve as a result of drilling efficiencies and further adoption of pad well drilling. In a flat pricing and rig count environment, cost management is going to be more be extremely important and we anticipate better cost optimization will result from our strategic initiatives. We're maintaining close contact with our customers to better understand their budget plans for the remainder of the year. We want to be clear that we expect North America margins to increase the balance of the year.
And finally, we're committed to growing our international revenues and margins and achieving a better geographic balance in our business going forward. I think our performance this quarter speaks to the progress we're making on that front. And now Mark will provide some additional financial commentary. Mark? Thanks, Jeff, and good morning, everyone.
Our corporate and other expense came in at $108,000,000 this quarter, slightly lower than expected due to some insurance reimbursements for legal costs associated with the Macondo litigation as well as decreasing costs related to our corporate initiatives. Approximately $34,000,000 of our corporate costs were for continued investment in Battle Red and other strategic initiatives. The cost of these initiatives will be declining over the next few quarters. We anticipate the impact of these investments will be approximately $0.02 to $0.03 per share after tax in the 3rd quarter. In total, we anticipate that corporate expenses will average between $110,000,000 $120,000,000 per quarter for the remainder of the year.
We continue to benefit from the strategic realignment of our international operations completed last year and the continued expansion of our international business. Our effective tax rate this quarter came in at 29% in line with the low end of previous expectations. We anticipate though that we might see a slight increase to about 29.5% for the Q3. Our capital expenditure guidance of approximately $3,000,000,000 for the full year remains unchanged. Throughout this quarter, we have continued to pursue in earnest a settlement to resolve a substantial portion of the private claims pending in the Macondo multi district litigation.
However, discussions among the parties to the proposed settlement have recently slowed, while BP challenges certain provisions of their previous settlement with the plaintiff steering committee, including a current appeal in the 5th Circuit Court. Now we continue to believe that a reasonably valued settlement is in the best interest of our shareholders. But given the complexity of the current situation among other parties, it is difficult to estimate when or if the resolution through settlement can be reached. In the meantime, we'll continue to argue our defense against any liability in the courts. No adjustment to the Macondo reserve was recorded during the and it's possible that we may need to adjust our reserve estimate up or down in the future.
At this time, our reserve estimate does not include potential recoveries from our insurers. However, we did reach a favorable agreement with a portion of our insurers during the quarter, which among other things allows us to continue to be reimbursed for our legal cost. As we communicated in our Q1 call, we intended to be more aggressive in our Q2 common stock repurchase activity. During the Q2, we upsized our revolving credit facility from $2,000,000,000 to $3,000,000,000 and used the excess liquidity that transaction created to repurchase 23,000,000 shares of common stock. Last week, our Board of Directors approved increasing the authorization for future share repurchases to $5,000,000,000 We're currently evaluating the best available repurchase methods.
This increased authorization together with the 39% increase in dividends announced in the Q1 is
is a reflection of our growing confidence
in the strength of our business outlook and our continuing commitment to shareholder distributions. Going forward, we believe the company will generate sufficient cash flows to enable us to grow our business, increase shareholder returns and maintain flexibility to take advantage of any strategic opportunities we see. Now moving on to our near term outlook. For our international business, we expect stronger revenues and margins during the second half of the year, but weighted more heavily to the Q4. For the Eastern Hemisphere, we're currently expecting 3rd quarter year over year revenue growth to be similar to the Q2 with a modest sequential improvement in margins.
Latin America growth is expected to be muted by the activity curtailment in Mexico, but we should see a moderate sequential improvement in revenue with margins approaching the mid teens. And for North America, we anticipate a flat U. S. Rig count for the Q3. However, we expect to see the seasonal rebound from breakup in Canada along with stronger activity levels in the Gulf of Mexico and we anticipate the net result will be modestly higher sequential revenues and margins.
Now I'll turn the call back over to Dave for some closing comments.
Dave?
Okay. I know a lot of people were dialing in late, So let me give you a quick summary of what we've said today. For North America based on improving activity levels in Canada and the Gulf and continued efficiency gains for U. S. Land, we expect margins to continue to improve for the balance of the year.
As Mark said, in Latin America, we feel confident that revenue and margins can improve in the second half with margins approaching the mid teens in the Q3. For the Eastern Hemisphere, our outlook remains unchanged. For the full year, we expect revenue growth in the mid teens with margins in the upper teens. And our aggressive buybacks in the 2nd quarter and the increase to our repurchase authorization clearly demonstrate our growing confidence we have in the strength of our entire business outlook. And finally, we have been and will continue to be relentlessly focused on delivering best in class returns.
So with that, let's open it up for questions.
Thank Our first question comes from Bill Herbert of Simmons and Company. Your line is now open.
Thank you. Good morning. Dave, I'm curious and just sort of weaves into Jeff's narrative with regard to the frac of the future and Battle Red, but C and P margins in this quarter were actually a pleasant surprise for me. And I'm just curious in a relatively labored E and P capital spending environment, sure, with well count and stage counts increasing, but overall, activity relatively flat rangebound commodity prices as it were and free cash flow generation still relatively challenged. How high can C and P margins in North America actually go?
Yes. I think, Bill, we have always said that we see no reason that in a reasonably robust gas market that we should not be able to achieve normalized margins. And for us normalized margins would be in the mid-20s. And so obviously, we're going to need help in gas from the gas market. But with the liquids market, I think underpinning sort of how low margins can go and you add to that the efficiencies that we see going on with respect to what we're going to get out of Battle Red and Frac of the Future, I can see a path there.
And as I said, we're going to have to get a little help from gas. And obviously, as we go forward into the balance of the year, we'll get some help from Canada.
Okay. And with regard to your prophecy for, I believe, full year margins for Eastern Hemisphere in the high teens. The only part of that equation which looks still somewhat ambitious to me relative to first half margins is Europe Africa CIS, which given what we did in the first half implies a relatively vigorous rate of improvement in the second half of the year. And what exactly is the roadmap for margin improvement Europe Africa CIS as the balance of the year unfolds?
Bill, I'll let Jeff handle that one.
Okay. Thank
you. I mean part of that path is kind of the pickup across Europe. We see some improving activity kind of through Scandinavia. We talked about project wins there. So that's certainly to the positive.
We also see kind of the sub Saharan activity picking up around the pre salt. So we see a path to improving margins in the back half. But certainly, the North Sea improving is a positive. And then also our activity in Russia should improve as well.
Thank you. Our next question comes from Jim Wicklund of Credit Suisse. Your line is now open.
Good morning, guys. The $32,000,000 mark in the quarter for the improvements in supply chain and all the continued improvements in Battle Red. I think Battle Red was supposed to go live this quarter and you're talking about being implemented in Q1. You guys have spent a lot of money doing this and so we assume that's an investment. And so how long do you think it will take to recoup the investments you've made?
And when does that quarterly investment start to approach 0?
Well, the Battle Red project, there are various elements of it that are rolling out each quarter as we go. So we talked about that we expect the whole project to be completed by the Q1 of 2014. But there's some fairly critical elements that have already rolled out like timekeeping and things of that nature. There are elements that will begin to roll out even this quarter and this next quarter and Q3 that will have an impact. We've tracked it.
We've looked at the cost very carefully. Most of as Jeff said, most of Battle Red is really around working capital and cash, but there is some fairly large savings in terms of headcount as well. We're going to give more data for all of you when we have our Analyst Day in November along all these projects and it's more specific information about the savings that we see. But just suffice to say, we're pretty excited about what we see right now, believe very much in these projects and what they will deliver and I think you will be pleasantly surprised when we give that data as well.
I love being pleasantly surprised. It's one of my favorite things in line. Very good. So a follow-up question. In the U.
S, the concern still exists that we all know that rig count isn't a very good denominator anymore. And even that said, we don't have a lot of confidence in wells and footage because it's not reported very well. How much is rig efficiency running? How much is service intensity running? With a flat rig count in the second half of the year, how much can you really grow revenue?
Is that a 5% number? Is that a 10% number?
I think we're still kind of at the leading edge, Jim, with respect to the amount of pad drilling. In fact anecdotally, when we talk to operators, they would describe what's been done until now as drill and hold and arguably a bit of exploration. Even some really big operators have said that they were waiting to really go full on development. So we've seen probably upper we've seen upper single digits type improvement in terms of efficiency even in the current year. That's on the back of double digit efficiency gains last year.
So I expect there's still headroom to grow around that scenario.
Thank you. Our next question comes from Angie Sedita of UBS. Your line is now open.
Thanks. Good morning.
Good morning, Angie.
Really very good to see the continuation of the above peer group growth rates in the international revenues and operating income, what drove you essentially modestly increasing your Eastern Hemisphere margin guidance from essentially the mid teens to now the high teens? Were there specific regions or countries that appear to be a bit better than you originally expected?
Yes. Thanks, Andy. A lot of that's built on the back of what we've seen in Asia. I mean, we've really come on strong in Asia. We've seen the kind of growth throughout the region and have no reason to believe that necessarily that abates.
Key contract wins last year, we're seeing those get started and grow into their grow into the types of margins we were expecting out of those and then we followed those up with a few more wins.
Predominantly stemming from Asia, fair?
Yes, fair enough. Yes, Certainly leading in Asia.
Okay. And then as a follow-up or unrelated follow-up on U. S. Pressure pumping, I believe you're essentially the only company that's near 100 percent utilization. In prior conversations, you indicated that you believe that the rest of the market could become balanced by early 2014 and absorb this 20% overhang.
Do you still believe that timeline? Or is that beginning to be a bit pushed out?
I think that timeline is beginning to push out just a little bit and that's on the back of what we've seen in terms of the overhang that's still there. The thesis we stay with in terms of sort of the longer things go cannibalization starts to occur of equipment in the market. So still believe there's the ability to consume the overhang ratably over time, but don't see that as necessarily a Q1, 2014 event. I think when we initially made that forecast, our expectations about rig count growth for the year, ANGI, were a bit higher. And as you heard, we're moderating that a bit and sort of assuming that we're going forward flat rig count efficiency levels have run higher, rig count lower.
I think the combination of both sort of says we probably had a little bit more a little longer overhang in this pressure pumping market.
Thank you. Our next question comes from wakar Sied of Goldman Sachs. Your line is now open.
Thank you. Your margins and revenues in D and E side for North America were a little bit lower. Is that all primarily Canada? Or is there pricing there as well? And then what's the outlook for the remainder of the year in D and E?
A lot of that is Canada. That's a good D and E market for us. And obviously with rig count, the breakup slowdown, we feel that more so. Have we seen some pricing pressure? There hasn't been some pricing pressure in those other service lines.
But again, see efficiency efficiency of the drilling activity taking that out, but the again primarily Canada.
So margin should go back to the 18% kind of level in the second half in North America D and E?
Maybe a little bit softer than that, but that's directionally the right way.
Now in the Bakken, there was some disruption in activity in the Q2 and completion activity was delayed because of the rains. Did you experience that? Or because that's a pretty large market for you guys or not?
Yes, we did. I mean, we had a bit of impact from that. The weather never helps us through the spring in that market. And even in Canada, there was the follow-up to breakup with the flooding that happened in Calgary. So it was a bit of a tough spring throughout that area.
Certainly don't expect that to repeat in the second
half. Thank you. Our next question comes from James West of Barclays. Your line is now open.
Hey, good morning guys.
Good morning, James.
Jeff, last quarter you had alluded to in North American Simulation that you guys were going to seek some pricing increases as you renegotiate the long term contracts. Now it seems like you're kind of pushing out when the industry comes back into balance. But curious if that still is your intention. And as we get into your rollover season here what the feedback has been from your customer base?
So let me clarify. In terms of the discussions we're having with clients, better wells are still very important. And so that plays to our strength in terms of designing custom chemistry for the best production, the subsurface insight that allows us to design the best producing wells. So those continue. But as we've said, we've continued to see some pricing pressure certainly variable across different basins.
So I guess the pricing pressure doesn't go away as long as there is the overhang out there of excess equipment. But I think our technical ability to sell into those contracts is still very good.
Okay. Fair enough. And then maybe just a follow-up on international pricing for me. Dave, you mentioned in your comments that it was still the gains were still elusive. It seems like it's the bad behavior is out of the market now.
But your competitors are at least getting somewhat more constructive. And I'm curious on why you think given the rate of growth that you're seeing and that your competitors have been seeing that why that pricing pressure is there pricing power still elusive?
Well, I think James, a couple of reasons. One is that the price in some of these tenders in the international markets are still so large in terms of revenue stream and duration that everyone tends to sharpen their pencil when they tender and price these things. Number 2, the ones that were tendered and won several years ago all had upsell and new technology strategies in them, all of which take a while to work their way through. So as I said, at this point in time, I think our focus is on increasing margins through better utilization, more efficiency. We have not seen a pricing inflection point even with increased spending because customers are really pretty much taking it slow and steady in terms of their increase.
And typically slow and steady doesn't lend itself to a major pricing inflection point, because all of a sudden a lot of capacity is stripped of the market. So as I said, the international market is playing out almost exactly as we saw it. And I believe we got a pretty good handle on what's going to happen over the next couple of quarters.
Thank you. Our next question comes from Kurt Hallead of RBC Capital Markets. Your line is now open.
Thank you and good morning. Just wanted to get some clarification on one thing. I think Dave you mentioned that there's going to be the Eastern Hemisphere going to be driven by Saudi and Asia. And then I think there was a question earlier about the margin improvement. And I thought I heard that was being driven mainly by Norway and Sub Saharan Africa.
So I guess my question is, can you give us some update on what you expect in terms of potential margin improvement contribution from the Middle East to that Eastern Hemisphere dynamic? Is that primarily coming out of improving profitability out of Iraq? Or is it coming from improved activity in Saudi?
I think Kurt, the Jeff was responding to a question specifically on why the Europe, Africa, Africa Russia operation was improving its margins. And I think his discussion on Norway, Continental Europe North Sea was reflective of that. If you sort of pull all the way back in terms of the Eastern Hemisphere, even though we're proud of our operation in Europe, Africa, CIS, the action really is in the Middle East and Asia right now. And so our Middle East operations will continue to expand. We're really happy with what we have going in Saudi.
Our operations in Iraq have stabilized. And then as Jeff has mentioned, almost all the way across Asia, we're seeing great success. So we're really happy with our Eastern Hemisphere portfolio right now. We haven't mentioned some of the African countries, but they continue to do better. So overall, I think that across the board, we're happy with where we are in Eastern Hemisphere.
It's just that some are driving forward a little bit faster.
Okay. And then thanks, Dave. And then the follow-up to that with respect to Iraq. Do you have a general time frame as to when you think Iraq may become neutral or net neutral to your Middle East, Asia margins?
It's neutral now. In fact, it was breakeven last quarter, slightly profitable. It's more profitable this quarter. We're positive on the outlook for Iraq. And I think it will be a little bit slower and more measured as we go forward, but certainly more profitable.
Thank you. Our next question comes from Brad Handler of Jefferies. Your line is now open.
Thanks. Good morning, guys. Hey, Brian. Could you guys just speak a little bit more specifically to what's happening in Egypt? From your business perspective?
Yes.
Obviously, it's not going and hitting on all cylinders at this point in time. The customers have dialed back a little bit. One of the big issues we have is because of the concerns the government have, the ability to move around in the desert has been somewhat hampered, especially the ability to move explosives around. And obviously explosives are key to our business in terms of completing the wells. And so that's just made the logistics of doing our operation there a little bit more difficult.
It hasn't been shut down, but it clearly has been ratcheted back. And obviously, when you ratchet back on the revenue and add a logistical cost, it really starts to impact your margins more than it impacts your revenue. Right.
But you all right. So you guys have you have kept all the crew and whatever expat crew is in country and
Yes, we have actually very, very few expats in a place like Egypt, but we have maintained our crews. That's correct.
Got you. Okay. An unrelated follow-up, Mark, what was the shares outstanding at the end of 2Q? That's a great question. We had 917,000,000 shares outstanding at the end of the quarter.
The part when you try to do the averaging through the quarter, right, most of the $1,000,000,000 share buyback happened in May June and so the averaging effect had a little bit different effect.
Thank you. Our next question comes from Doug Becker of Bank of America. Your line is now open.
Thanks. Jeff, I think you indicated 50% of the frac fleet will have the Q10 pumps by the end of 2015, which I think implies about 50% conversion of the fleet over 3.5 years give or take. Ultimately just trying to gauge if it's reasonable to assume that the full fleet would be converted in a total of 6 to 7 years, kind of a similar environment to
what we've seen over the
last couple of years? And if everything fell into place, how quickly could you have Q10 pumps and all on the entire fleet?
Yes. That's the right pace. We expect to be by 15% at about half. But what I would say is caution is that we're doing this sort of ratably as the market allows and as equipment is taken outside the U. S.
Equipment retirements occur. But we have continued to retire equipment in order to get the equipment into the field. So that's the right pace kind of the 5 to 6 year pace, but that would to a certain degree be limited by the market. We wouldn't get over our skis if the market didn't allow it.
How quickly could you if 550 gas international and conventionals are ramping up, how quickly could you in the perfect scenario?
Very quickly. I mean that's my reference to our manufacturing capability allows us really to turn more quickly than probably anyone in the marketplace around bringing equipment forward. So we would love to have the opportunity to do that.
Thank you. Our next question comes from Dave Anderson of JPMorgan. Your line is now open.
Hey Dave, in your prepared remarks you mentioned something about 50% of drilling in the U. S. Is on pad drilling. I was a little surprised by the number. It seems
a little higher than I
was thinking. I was in was that a number for Halliburton? And if so, can you just tell me where do you think that number goes say by the end of 2014?
No. The number Dave, that's our view of where the market is today not just for Halliburton. And I think that as we've tried to allude over the last couple of quarters, I think the people that are analyzing in our industry have got to move away from rig count. They've got to move away from well count and really look at sort of horizontal footage drilled. And given the position that we have in the U.
S. And given what we see out there, we think that basically the pad drilling is 50% or so. The other thing that you see is pad sizes are getting much larger and that just drives more efficiency and more service intensity.
And I was just wondering if you can help me quantify this impact. Like let's just say you took 5 wells on pad drilling versus 5 wells kind of standalone. How would you think that your margins should be different between those 2 wells? Or is it on a reduced cost? Or whatever the best way
to measure that impact is?
Well, the margins are better on the back of the number of turns we get on the equipment. So if we're rig up on a single location, we have even particular equipment that allow us to move from well to well without having to move the equipment at all. So if we think in terms of start to finish or time between wells, we are just working more on a pad and the larger the pad the more we work as opposed to breaking down and moving away to somewhere else. So is
that like a 20%, 30% increase in margins something along those lines?
Well, I think obviously we know what that amount is, but we're not going to tell the world.
Thank you. Our next question comes from Jeff Tillery of Tudor, Pickering, Holt. Your line is now open.
Hi, good morning. Hi, Jeff.
The discussion around Q3 North American outlook, so top line growth being driven by Canada and Gulf of Mexico coming back, it seems to imply that the U. S. Land business kind of trajectory through the course of Q2 was pretty flattish. Is that correct? I guess what was my question?
For Q2, we saw improvement in America land, again offset by those other items. So, no, I wouldn't infer that.
I guess, so was that improvement so April through June that was better than the March exit rate? I guess, is the way I'm trying to
Yes. On a stage count basis, we're seeing an improvement. So we're back kind of consistent with what we saw middle late last year middle sort of Q3 ish of last year. So I mean we're seeing the activity rebound.
And then the unrelated follow-up question I had just around Latin America. So we see the revenue improve in the second half of the year. But if I was to put kind of bounds around what's reasonable, is it fair to think kind of low side case of revenue growth of 5%, high side case of 10% full year
in Latin America year over
I think your 5% number is pretty good. Okay.
All right. Thank you.
Thank you. Our next question comes from Scott Gruber of Bernstein. Your line is now open.
Good morning.
Good morning. Good morning. Given a more tempered outlook here for rebalancing in the pumping market, I assume you're not considering expanding the size of your U. S. Pumping fleet during the first half of twenty fourteen.
I assume that's correct because you didn't increase your CapEx for the second half of the year?
No, that'd be correct. Our expectation is to kind of stay where we are.
Okay. And then how do you think over the medium term about that choice between continuing to improve margins, which is clearly the goal today and the opportunity to
market.
Personally, I think the U. S. Market should be a good market over the medium term as the industry moves to monetize cheap natural gas. Are you thinking about a certain margin level that you want to get to before you start adding capacity? I mean, you're above your cost of capital today.
Is it getting back to those normalized margins that we should think about before you start increasing your CapEx?
Look, we always start with returns first. So everything that we do in this business is around returns. And so long as we're happy with our returns and we're getting equipment to work, we wouldn't take share at the expense of returns. And really don't know that I mean, but with on the back of things that we're doing with Battle Red and Frac of the Future, I don't see those two things as mutually exclusive. Some of the systemic things we're doing allow us to grow share even with the equipment we have or with the same level of equipment that we have.
Yeah. I think there are
2 things to consider Scott. 1 is that with pad drilling and the efficiency that our equipment is working today, as we look at it, you're creating effective utilizable space on the calendar as we work faster and more efficiently. The second thing, which is I think unique to Halliburton, remember we're retiring equipment as we roll out our frac of the future, but that equipment was working today, still viable equipment. And right now because we don't see the need for excess equipment, we're parking it, possibly destining that equipment for our international operations along the way. But if the right opportunity presents itself along the way, we have the ability to redeploy some of that equipment back into the U.
S. Market or not pull it out of service in order to capture share when we see that we have an opportunity to continue to get very good returns and work for the right customers in the right basins with the right
technologies. Sam, we'll take one more question.
Thank you. Our final question comes from Robin Schumacher of Citi. Your line is now open.
Thank you. I wanted to ask about Mexico, go back to Mexico for a minute. The contract that you won in to Conspec, I believe you talked about cost recovery and then I think there's a fee per barrel arrangement after that. So can you describe exactly how that works and why there was why you believe there wasn't a much broader interest among oil service companies in these to contact blocks?
Yes. The cost per barrel or the fee per barrel is really the smaller piece of that type of project. Really, it's a situation where we provide services into the project and then earn cost recovery to get paid at what we believe are certainly accretive margins to our business. I think the interest by others, I can't say what others were necessarily interested in or not, but I would say that this is very services that it takes to do all of that work. So the one that the hamapas that we won, we are really comfortable with where we are.
And really the last thing that prevents a broad group from going into that is quite frankly the capital upfront that's required to embark on these types of things.
I see. Okay. So on these integrated projects that you described that are coming up in Mexico, are some of these projects that will involve sort of high end technologies? Or are these going to be really very competitive types of tenders?
Well, this will be both. I think it's a combination. What we're describing are all of the integrated drilling not like the incentivized rounds that we just finished talking about, but drilling wells for Pemex in a lump sum type fashion. And those range from some more simple to some that are actually quite complex. So I think we'll see competitive it will be competitive just given the size of the activity.
But the type of technology required, I do think will be important as those projects are lit.
Thank you. And at this time, I'd like to turn the call back to management for any closing remarks.
Okay. Thanks everybody for your participation. We'll be doing follow-up calls over the next couple of days. And Sam with that you can go ahead and close the call.
Thank you. Ladies and gentlemen, thank you for participating in today's conference. This does conclude today's