Malcolm Theobald - Vice President of Investor Relations Simon Ayat - Chief Financial Officer, Executive Vice President Paal Kibsgaard - Chief Executive Officer, Director

Kurt Hallead - RBC Capital Markets James West - Barclays David Anderson - JPMorgan Judson Bailey - ISI Group Bill Herbert - Simmons & Company Scott Gruber - Bernstein Ole Slorer - Morgan Stanley Michael LaMotte - Guggenheim Bill Sanchez - Howard Weil Angie Sedita - UBS Jim Crandell - Cohen Jeff Tillery - Tudor, Pickering

Ladies and gentlemen, thank you for standing by, and welcome to the Schlumberger earnings conference call. At this time, all participants are in a listen-only mode. Later, we will conduct a question-and-answer session. Instructions will be given at that time. (Operator Instructions). As a reminder, this conference is being recorded. I would now like to turn the conference over to your host, Vice President of Investor Relations, Mr. Malcolm Theobald, Please go ahead.

Thank you, Greg. Good afternoon and good morning, and welcome to the Schlumberger Limited second quarter 2013 results conference call. Today's call is being hosted from Paris where the Schlumberger Limited Board meeting took place yesterday. Joining us on the call today are Paal Kibsgaard, Chief Executive Officer and Simon Ayat, Chief Financial Officer. Our prepared comments will be provided by Simon and Paal. Simon will first review the financial results and Paal will discuss the operational and technical highlights. However, before we begin with the opening remarks, I would like to remind the participants that some of the information in today's call may include forward-looking statements as well as non-GAAP financial measures. A detailed disclaimer and other important information are included in the FAQ document, which is available on our website or upon request. We will welcome your questions after the prepared statements. Now, I will turn the call over to Simon.

Thank you, Malcolm. Ladies and gentlemen, thank you for participating in this conference call. Second quarter earnings per share from continuing operations, excluding charges and credits was $1.15. This is an increase of $0.18 sequentially and is $0.14 higher when compared to the same quarter last year. During the quarter, we completed the wind down of our operations in Iran and as a result we have now classified this business as a discontinued operations. All prior period amounts have been restated. As previously disclosed, we completed the formation of our OneSubsea joint venture with Cameron prior to the end of the quarter. We recognized $1 billion gain in connection with this transaction which equates to $0.77 in terms of EPS. We also recorded $0.26 of charges relating to the impairment of drilling related equity investments. From an operational perspective, we had a very strong quarter. Oilfield services second quarter revenue of $11.2 billion increased 5.8% sequentially, pretax operating income increased 15.9% sequentially while the pretax operating margin improved 178 basis points to 20.4%. Sequential highlights by product group were as follows. Reservoir Characterization revenue of $3 billion increased 9.6% and pretax income grew by over 25%. This resulted in margins improving by 380 basis points to 30.1%. This growth was driven by very strong performance in both Wireline and WesternGeco combined with the seasonal rebound in SIS software sales and maintenance. Drilling group revenue of $4.3 billion increased 4.4% and margins improved by 97 basis points to 18.7%. These increases were largely attributable to the Drilling and Measurements and M-I SWACO on robust international activity. Production group revenue of $3.9 billion increased 4.4% while the pretax income increased 12.6%. This resulted in margin expansion of 116 basis points to 15.9%. Growth was led by Well Services as a strong performance internationally and in US land more than compensation for the impact of the spring break-up in Canada. Completions and one intervention were also significant contributors to the growth. Now, turning to Schlumberger as a whole, the effective tax rate excluding charges and credits was 23.3% in the second quarter compared to 23.8% in the previous quarter. We continue to expect the effective tax rate for the full year of 2013 to be in the mid 20s, hwoever, this can vary on a quarterly basis due to the geographic mix of business. Yesterday, our board of directors approved the new $10 billion share repurchase program to be completed at the latest June 30, 2018. Our strong projected cash flow over the next five years allows us to increase the level of share buybacks while also maintaining enough flexibility to continue to take advantage of growth opportunities. Let me take this opportunity to remind you how we manage our cash flow. Our first priority is to reinvest into the business to drive growth. We do this through CapEx and the investment we make in R&D and future revenue streams. From a dividend perspective, over the past 10 years, we have increased our dividend on average by 13% per year. We will continue to review this on an annual basis with our board. After that, we will continue to be strategic when it comes to M&A, then the balance will be spent on stock buybacks. For the first six months of this year, we have generated $3.4 billion of cash flow from operations. Net debt at the end of the quarter was $5.6 billion as compared to $5.3 billion at the end of the first quarter. Significant liquidity events during the quarter included $906 million of CapEx, $600 million payment to Cameron for the OneSubsea transaction and $500 million of stock repurchases. During the quarter, we repurchased $6.84 million shares at an average price of $73.7. CapEx is still expected to be approximately $3.9 billion as compared to the $4.7 billion we spent in 2012. Now, I will turn the conference call over to Paal.

Thank you, Simon. Our second quarter results were strong as international activity recorded significant progress and North American results benefitted from solid execution in land and increasing deployment of new technology in deepwater areas. Sequentially, revenue was up 6%. Margins expanded by 178 basis points, which together yielded a 16% growth in operating income. Compared to the same quarter last year, operating income was up 12%. The results were driven by solid activity levels in all our main markets as well market share gains for a number of our product lines on the back of new technology sales and our strong execution and integration capabilities. I am pleased with the overall results and even more so with the consistency in our business performance throughout the company seen, for instance, in the margin levels of our four main operating areas, which are all at or above 20%. The focus on the quality and efficiency of our execution is also reflected in our incremental margins, which were north of 50%, sequentially, as well as the cash flow from operations which was $2.3 billion driven by both, improving asset utilization and reduction in the use of working capital. The strength in our international business was again evident in the second quarter with year-over-year revenue growth of 12% and margin expansion of 173 basis points to reach 22%, making up over 70% of the operating income of the quarter. Activity and customer plans confirmed our expectations for the year in all our major growth markets, while revenue per rig continued to steadily increase as a function of new technology sales, increased integration related activity and a favorable business mix. Our ability to consistently execute remains critical in the international market and is a driver for both, our market share gains and superior margin performance. While we continue to replace competition on contracts where they are unable to deliver, we are becoming more and more selective in terms of where and when we do so. In Latin America, the revenue was flat, sequentially, despite a 2% drop in rig count, while margins increased 107 basis points to 20.6%. On a year-over-year basis, revenues increased 3%, while margin expanded 153 basis points. Our Latin America business showed commendable resiliency this quarter by maintaining laser focus on execution, technology sales and cost control overcoming both, activity headwinds and new contract mobilizations and startups. In Mexico with the third big round for production intensive contracts was concluded where we ended up bidding for only one of the six blocks. Drilling activity remained soft in the North and East regions of the country following the budget shifts announced in the first quarter. In Venezuela we signed a new agreement with PDVSA and we are now in the process of ramping up our activity in the country while payments are on plan. Elsewhere in Latin America, the Shushufindi SCM project in Ecuador is progressing well with production levels well above the agreed targets. While, in Argentina, we continue to be active in reservoir studies and well side operations relating to Vaca Muerta shale development. In Brazil, we continued to mobilize resources during the quarter for the new contract signed with Petrobras although overall activity levels were down sequentially. We have several new IPM projects starting in the second half of the year, however the overall activity level is expected to remain flat to slightly down for the rest of the year. Overall, our outlook for Latin America remains unchanged with 2013 being a transition year in terms of activity for the region and we remain comfortable with our position, our plans as well as the actions we have taken to handle the somewhat challenging business environment. In the Middle East and Asia, revenue grew 11% sequentially on a 3% rig count increase while margins increased 178 basis points to 24.6%. On a year-over-year basis, revenues increased 28% while margins were up by 330 basis points. In the Middle East growth was again spearheaded by Saudi Arabia and Iraq but our United Arab Emirates and Oman geo markets also posted strong results. Common to all there markets is that we have gained noticeable share in the past quarters. Our business in Saudi Arabia continues to grow through a diverse portfolio of projects on both land and offshore and driven by both drilling and rigless activity. In Iraq, we have on the back on an unmatched execution track record built up a significant business that is now starting to yield excellent results. Activity levels continue to increase both in the North and in the South of the country and with our business footprint and contract portfolio, we have clear leadership in what is shaping up to be a very interesting market for us. Asia also contributed strongly to the area results by delivering a record revenue in four geo markets driven by robust market share and new technology sales. China led the Asia growth on a rebound from seasonally low land drilling and simulation activity in the previous quarter and also helped by an upswing in offshore activities. We also posted very strong in Australia, driven by continued growth in unconventional activity on land as well as offshore and deepwater activity in the Northwest and Papa New Guinea. In Europe, CIS and Africa, revenue was up 10% sequentially and margins increased 275 basis points. On a year-over-year basis, revenues increased 7% while margins increased 33 basis points. As expected, Russia led the growth in the second quarter as the high volume land as well as the offshore business entered the most active phase of the calendar year. EMP investments and activity levels in the country remained very strong in terms of offshore and land activity as well as for exploration and development and Russia will be one of our fastest growing markets in 2013. In the North Sea, WesternGeco saw strong activity as the seismic acquisition season started while the offshore drilling rig count stayed more or less flat. In North Africa, rig activity in Nigeria started to rebound following the security incident in the first quarter while rig activity in Libya remained flat due to delays and ongoing security challenges. In Sub-Saharan Africa, activity in the Gulf of Guinea as well as in East Africa was robust. On the other hand, activity in Angola was subdued in the second quarter due to project delays. However, the activity outlook for the second half of the year remained strong driven by both exploration and development projects. In North America, revenue was up 2% sequentially while margins increased 65 basis points to reach 19.7%. On a year-over-year basis, revenues were flat while margins were down 83 basis. In the North America land market, the rig count dropped 14% sequentially driven by the Canada breakup and also impacted by the June flooding in Alberta. While the downwards pricing trend in U.S. land continued in the areas of drilling, simulation and wireline, although this slowed in pace during the quarter. However, continued strong drilling efficiency, resulting in solid growth in horizontal wells and frac stages completed partly offset these headwinds. Looking at our land performance we continue to execute very well in our product lines and we also see a gradual improvement in the uptake of our new shale technologies throughout the characterization, drilling and production groups. In the U.S. Gulf of Mexico, the deepwater rig count is now 17% above pre-Macondo levels and on a year-over-year basis activity has increased by 30%. The call for reliable and efficient service delivery in addition to risk mitigation technologies continues in this growing market and is yielding very strong result for a number of a higher margin and higher market share product lines. In addition to the Dual Coil fleet operating in the Gulf of Mexico, WesternGeco also started isometrics operation in Eastern Canada during the quarter. Turning next to technology. During the quarter, we closed the OneSubsea joint venture with Cameron and the JC is now operational. Cameron, with its long history of innovation and firsts in the subsea market is an industry leader in design capability, manufacturing excellence and successful installations. In addition to this, Schlumberger brings a deep understanding of the reservoir as well as industry-leading well completions, subsea processing and integration capabilities. Through the combination of these strengths, OneSubsea will offer best-in-class subsea solutions optimizing the complete subsea production system and helping our customers improve production and recovery from their subsea development. In other areas, we saw growing customer interest in a number of our new or recently commercialized technologies. In Wireline, the Saturn 3D fluid sampling probe is enjoying one of the most rapidly growing deployments of new formation of our technology for a number of years. Its ability to acquire reliable pressures and high quality samples in difficult reservoirs has been impressive. Reservoir Characterization, the SIS Studio Manager software, which went from concept to market release in only eight months is enabling and increasing number of customer geoscientists to access data, collaborate with peers and share best practices within [partout] workflows. Within the Drilling Group, new and innovative drillbit technologies recorded significant progress. Drillbits equipped with Stinger conical diamond elements that add stability and improved drilling speed have now made more than 650 runs in North America alone since their introduction in the first quarter and have achieved an average improvement of 15% in rates of penetration. In the second quarter, we commercialized the ONYX 360 rotating cutters that we believe will lead to dramatic improvements in different lengths in abrasive formations. Lastly, at the Production Group, joint deployment of LIVE slickline with ACTive coiled-tubing services demonstrated clear benefits in the efficiency and effectiveness of our well intervention services both, on land and offshore, and units were active in the quarter in both, Latin America and the Middle East. Let's now turn to the macro environment, where the business outlook for 2013 has remained largely unchanged since April as expansion in the global economy remained soft. In summary, the U.S. has shown little or no impact of the financial sequester. The Eurozone is still in a two-year recession although the risk of any concrete to leave the monitor union appears reduced. And, recent Chinese data have been mixed with the outlook for long and progressive soft landing remaining unchanged. The oil market picture is also largely unchanged. The market is more comfortably supplied than it was in 2012, but spare capacity remains below pre- Libya conflict levels. The year-on-year increase in North American supply is enough to face both, increasing global demand and the production declined in other non-OPEC producing countries. The call on OPEC remains unchanged and is in line with the group's production target of 30 million barrels per day. Overall, the market continues to support Brent prices over $100 per barrel. For natural gas, the apparent rebalancing of the U.S. market is still fragile as gas production remained steady and as the power sector has already switched back to coal in some regions on higher gas prices. Internationally, Asian LME prices eased on weaker Chinese demand trends, but remained close to oil parity. While in Europe regional supply declined from the North Sea and very cold weather supported highest spot prices. Despite the overall slow progress in the economic environment, the latest releases of the third-party E&P spending surveys, so offer durations of upstream CapEx estimates making 2013 the fourth consecutive year of double-digit worldwide gains driven by the international and offshore investments notably in the Middle East and Asia regions, while the North American spending remained flat to slightly up. These estimates are further confirmed by the recon outlook that shows double-digit growth in a number of both shallow water and deepwater rigs active worldwide and a 6% growth in the international land rig count in 2013. In this market, we continue to focus on [key] control, which is the quality, efficiency and integration aspects of our operational execution. Through this focus, which permeates our entire organization, we continue to demonstrate our ability to deliver tangible results today as can be seen by our revenue market share gains, unmatched operating margins, strong cash flow and consistent double-digit growth in earnings per share. We also remain confident in the outlook of the industry, in our strategic position within the markets we operate in an in our ability to further improve all aspects of our performance going forward, which remains the overarching objective of the entire Schlumberger team. That concludes my remarks. I will now hand the call back to Malcolm.

Thank you, Paal. Greg, we will now open the call for questions.

(Operator Instructions). Your first question comes from the line of Kurt Hallead from RBC Capital Markets. Please go ahead. Kurt Hallead - RBC Capital Markets: Good afternoon where you are. A question, Paal, for you on the North American market. You continue to show some differential performance on the margin front despite the fact that and show improvement in terms of activity, revenue and margins despite an anemic rate progression and a lot of discussion here about the well count and so on. So I was just wondering if you can us a little bit of additional color as to what product lines that you see will be benefitting from the shift in the type of drilling that’s taking place in the U.S. marketplace and what kind technologies that Schlumberger has that will continue to enable Schlumberger to share differential margin performance going forward?

Well, I think if you look at what enables to show differentiated margins, I think its several things. Firstly, our ability to execute very well on land, whether that is on drilling or on pressure pumping but also the fact that we have a very well balanced portfolio in between drilling and production related activities on land as well as in between land and offshore. So we honestly have a very strong offshore business both rig related as well as seismic but what we have done in recent years is, starting off in 2001 was to restructure the business on land which in previous years, I would say, had underperformed and through that restructuring, I think, we are performing on par with the best if not better in most of our product lines. So if you look at the trends of drilling, in the North America land market now going towards more and more horizontal wells, predominantly focused on liquids, all our drilling segments obviously benefit from that. At the same time, our pressure pumping business through new technology deployments such as HiWAY are also benefiting from this. We also introducing to the market our own multistage completion technology, which has been a gap in our portfolio in recent years which also should enjoy quite significant growth going forward. So I think it’s a good balance between land and offshore, good balance between drilling and production on land and overall a very strong focus on execution. Kurt Hallead - RBC Capital Markets: And as a follow-up on that, with respect to the overall margin performance of Schlumberger, especially in the international marketplace, are you getting any sense that we are starting to see a shift in the industry that will demonstrate Schlumberger's relative product and services strength, whether its deepwater or otherwise? Do you think whether that kind of an inflection point in the marketplace or we are going to see these strengths of Schlumberger?

Well, if you look at our margin performance in international over the past couple of years, I think we have been highly differentiated continuously, right. So I think we have done well in our contracts strategy, what contracts we are prepared to take on and the ones that we see more as must wins. We have continuously introduced new technology and we are also leveraging very well, I think our overall size and infrastructure. So to your question, whether its an inflection, we don’t see any imminent inflection in big pricing at this stage. We are seeing a continuous uptick in another pricing indicator that we track which is revenue per rig. That is continuing to grow and going upwards. That obviously helps our profitability. What drives that up is new technology sales. It is our integration capabilities where we do more and more services and products on each rig and it is also down to the nature of the work that we take on. Typically take on the more complex and more intense work, because it is more difficult to do. If you perform well in that, that also is quite accretive to margins. So bid pricing, we still don’t see any imminent inflection but we continue to drive revenue per rig upwards through new technology, through integration and there's very solid execution. Kurt Hallead - RBC Capital Markets: Okay. That's great. Thank you.

Your next question comes from the line of James West from Barclays. Please go ahead. James West - Barclays: You mentioned in your prepared comments, the third party surveys, which of course you are well aware we do a very large survey. And, what we saw when we reran the numbers here in May and in early June was that international spending was creeping up about 300 basis points to 400 basis points. So, curious if you are seeing the same things from your customers who you are having the same post conversation that we are with. Then secondarily, which markets do you agree with what we showed as the biggest growth areas of kind of Middle East, eastern hemisphere in general and which seem like markets that are Schlumberger's backyard essentially. Do you see those as the best growth markets for this year?

Okay. So, to the first part of the question in terms of the spend, yes, if you look at the average of the spend surveys, we look at several. I think for international it was about 9% early in the year, and it was generally all of them revised upwards lately to average about 13%. So, we generally agree with that upwards revision. We see continued strong activity levels in the international market and those spend surveys are also I would say confirmed from the rig count outlook and also the rigless outlook in terms of activity that we have the second half of the year. So, yes, we are in agreement that that upward revision seems to be reasonable. Then second part of your question was? James West - Barclays: On the specific regions where the spending has increased?

Yes. So, we highlighted going into the year five major growth regions, right? So, we said that international would grow north of 10% this year. We would see growth in Latin America, but due to the kind of transitional nature both, in Mexico and Brazil as we indicated earlier in the year, we weren't expecting a lot of growth coming out in Latin America which is being confirmed and we said that the main growth markets would be Sub-Saharan Africa, Russia, Middle East, in particular Saudi and Iraq, China and Australia. Those were the five main drivers. So, basically and ECA and MEA were the main drivers of growth in international market. James West - Barclays: Okay. Then just a follow-up from me, the market share gains that you also highlighted in your prepared remarks, are those happening in those markets that are going the most rapidly?

I think, in general that's fair. I would say in particular in MEA, we are gaining quite good market share. James West - Barclays: Okay. Great. Thanks Paal.

Your next question comes from the line of David Anderson from JPMorgan. Please go ahead. David Anderson - JPMorgan: Paal, just a real quick [rig count] about six month behind schedule. Can you concur with that and does that have an impact on kind of your outlook for next 12 months?

Well, if you look at our view on the [rig count], we are still expecting the total rig count both drilling and workover to reach about 170 rigs by the end of 2013 or early 2014, so the rig count evolution in Q2 was flattish, but it is all about when new rigs arrive and how they are commissioned and so forth, but we are still expecting that we will reach the number that we have indicated earlier roughly by the end of the year or early 2014. David Anderson - JPMorgan: Okay. Then I just wanted to make sure you touched on that you can't expect bids from us. I was just curious what was about those contracts that kept away? Was it location, work, was it the contract structure or you guys just holding out for another set of tenders?

Well, let me just give you a little bit of background on our view on these production incentive contracts. So, we've been very clear about our interest in production incentive contracts, but we also stress the importance of picking the right project with the right terms. So, we evaluated all the 60s offered in the third in Mexico and based on the very detailed technical and commercially valuations we did, we only fund one field interesting. Now we've been at this field at the price that will give us the returns that we require and that is really factoring in the additional risks associated with these contract terms. The winner bid at a fee close to zero fee per barrel and basically we are not interested in doing that, so we did not win it. David Anderson - JPMorgan: Okay. One last quick question on some of the buyback you announced today. Could you just kind of give us a sense on your philosophy on the pace of that buyback? You talked about the cash flow you are generating over next couple of years. Should we expect the majority of that to go towards share repurchase? I heard on some type of broke in terms of the deal but it seems like you have an opportunity here to kind of accelerate that over the next, all it, I don’t know, three or four quarters here. Am I right in my assessment?

Okay. Well, thanks David. As I mentioned in my remark, that the buyback is basically a balancing number for us when it comes to utilization of the cash flow. You are right in your assumption of the cash flow. That's why we said latest by 2018. So as the cash flow proved to be significantly better than what we have factored in the five year scenario in making the $10 billion program, we will accelerate it. We did this in the past. We look at our excess cash over a period of time, taking into consideration the growth that we are anticipating in terms CapEx and as I said investment in future revenue stream activity, be it multi client or production incentive contracts and any balance will go into the buyback. Yes. David Anderson - JPMorgan: Okay, great. Thank you very much.

Your next question comes from the line of Jud Bailey from ISI Group. Please go ahead. Judson Bailey - ISI Group: Thanks, good morning. I wanted to ask a couple of questions on Mexico, if I could. The first is, that's obviously a big market for you guys. Are you there?

Yes. Judson Bailey - ISI Group: I am sorry. Obviously a big market for you guys, pretty-diverse. Pemex still has pretty ambitious growth expectations in next few years. It obviously pulled back activity in the North. I wanted to get your thoughts. They have the lot of tenders coming up and tenders in process and it would look like, you could see pretty strong growth in that market next year. In your view, is there any reason for skepticism that Pemex may be wouldn't follow through or is there else going on down there that would give you some caution in terms of the growth opportunities down in Mexico?

No, I don't see any reason for that. I do not think Pemex has signaled that there is a number of bids coming out for the remaining part of this year and probably into next year. We are going to actively compete for all of that work and we continue to see Mexico as a very interesting market for us. Judson Bailey - ISI Group: Okay, all right. Then next question, just on North America. Obviously, very strong margin results factoring in Canada and everything else going on in that market. With the continued growth in the Gulf of Mexico and let's just say that the U.S. landmark, it kind of continues at this methodical pace with very little pricing traction. How should we think about Schlumberger's margins in terms of, we would assume you would get some more market share gains, you would benefit from the very strong Gulf of Mexico and a rebounding Canada? Can you help us think about maybe the near term and the long term margins for the Schlumberger in the North America market?

Well, I would say that over the past year when there has been significant struggles in the pressure pumping business, I think we have shown commendable margin resilience and again, as I alluded to earlier, it is down to how we execute on land as well as the balance between land and offshore. So in terms of what the margin progression is going to be, the main uncertainty is still what is going to happen in terms of pricing on land. As I mentioned in my prepared remarks, we still saw pricing pressure both in the drilling, stimulation and Wireline product lines in the second quarter but that was slowing somewhat in pace. So assuming that the pricing is reasonably behaved and drilling efficiency continues to be the main activity driver going forward, I would expect us to show continued margin resilience and obviously we are looking to drive up margins in any operating areas. I can't promise you exactly how that’s going to progress but we have a lot of focus on margins in every part of our business and we will continue to look drive it up in North America. Judson Bailey - ISI Group: All right, great. Thank you Paal.

Your next question comes from the line of Bill Herbert from Simmons & Company. Please go ahead. Bill Herbert - Simmons & Company: Thanks, good morning. Paal, I was wondering if you could sort of reconcile on the one hand for double-digit E&P capital spending growth, not so much for this year but on a structural basis perhaps going forward internationally, and reconcile the tension between on the one hand the increasing need on part of the customer base to reinvest simply to keep production flat and on the other hand increasingly challenged cash flows in a range bound oil pricing burn and rising cost environment. What do you think ultimately happens over the next several years assuming range bound oil prices? Does the rate of E&P capital spending growth decelerate or what happens?

Well, I think we are still optimistic about the further need to increase overall E&P spending going forward, right? So, we saw the upward revision for the spend survey this year. And at this stage, although it's early to conclude our next year the customers need to go through their planning process, but we are still optimistic about the initial projections for 2014. The resilience in the spend as you say is linked to partly the working intensity linked to fighting decline, but also due to the overall size and complexity of the projects that are undertaking in particular in the international market. So, I think for the company, for E&P companies that potentially are or will be facing cash flow issues, we expect them to be likely to shift more of the spend within the E&P spend from more infrastructure related projects towards more well CapEx. So that obviously will be good for our business, because that's sort of where we make most of our money on, right? So, I think the general shift from infrastructure towards CapEx is where I expect to happen for those E&P companies that are facing cash flow issues. Bill Herbert - Simmons & Company: Okay. Then secondly switching gears. At the reservoir level, I'm curious as to what your views are with regard to the outlook for U.S. oil production growth, I mean, clearly it's been extremely vigorous. We are up about $1 million barrels per day on a leading edge basis that's 15% to 20% year-over-year, yet I think there is a healthy debate here with regard to the prospects going forward, the prospect of the Bakken growth flattening out and filling their production growths vacuum with other basins, perhaps not as easy as some contend. Where do you fall out with regard to the domestic production outlook going forward stronger for longer, or decelerating or too early to make a case either way?

It's a good question. First of all I would say that the overall production increases that we have seen on our North America liquids, they have been very impressive. We always maintained that it's too early to extrapolate the early production trends in terms of how great they see. Also, I think it's too early to conclude on whether the trends we are seeing on the Bakken, is something that is also sustainable, right? For the early production trends, I think we need more information to look at the production of these wells over a longer period of time and I think we also we need to look at the initial rates or the inflow performance for the wells that the operators are started to drill outside of the fairway, right? As they step out on the acreage, so I am going to have to go for option three of your multiple choice there. I think it's too early to say both, while we can extrapolate the initial overall trend from North America or whether there is any significant impact or the recent trend that we see in the Bakken.

Your next question comes from the line of Scott Gruber from Bernstein. Please go ahead. Scott Gruber - Bernstein: Paal, I found you comment about becoming more selective regarding when and where you chose you peers interesting. Is this a reflection of capacity constraints desires to avoid problematic contracts some of those? Why is the stance shifting?

Well, I think obviously if a customer calls upon us and wants us, generally, we will do utmost to serve them. At the same time, we also have to make sure that we prioritize putting our equipment into the customers that have initially selected us, and if we are going to go on replace the competitor on or their contracts, we obviously need a significant pricing increase from the initial rates that our competitors took the work on for, right? So, and there's also other strategic considerations as to where do we put our capacity while it's a priority in terms of the customer mix this well, so can't really going into the details of how we select, what to do. I would just say that we will always look to serve our customers as best as we can. But at the same time, we are continuing to look at how we optimize our business mix and how we maximize the return from the resources that we have up in operations. Scott Gruber - Bernstein: Okay. Then an unrelated follow-up. Can you discuss the efforts internally to improve the working capital management? If you look over the last six months you guys have held the line here on receivables and other current assets but I assume that you are not completely satisfied in the working capital at this point. Then if you have year end targets that you could share with us, that would be greatly appreciated?

Well maybe I will say a little bit about what I think the investment community call self help initiatives, right. So first of all, in Schlumberger we believe that in order to maintain and extend to our market leading position, we always need to do better tomorrow than what we did today. So, company wide programs addressing execution improvements they are not really sporadic or episodic with us. They are a way of life. So we have, in recent years or in the recent year, put more focus on working capital on cash generation. In the past before we had more focus on more cost and resource management to be trying to balance the focus on both cost and resource management with cash management. So we have specific programs running focused on capital efficiency, around receivables and also around inventory management and we build it into our business plans and we also build it into the incentives of the entire management team. So this is really how we try to put focus on it and what we put focus on in Schlumberger will generally do quite well.

I would like to add a bit to what Paal said. The last couple of years since the acquisition of Smith, you probably noticed that the working capital as percentage of our sales has gone up a bit. This was all planned. As a result of expanding certain segments or product lines of Smith internationally, which are more inventory intensive segments or products line, we had to increase inventory to meet the expansion that we have done internationally. One of the main reasons for acquiring Smith and integrating it with the rest of Schlumberger is also to use the footprint of Schlumberger, which meant that some of those segments that were mainly U.S. focused we took them overseas and therefore an increase in inventory. We have managed to do this now and going forward we will not have to increase it at the same pace that we have done before. Scott Gruber - Bernstein: Great, I appreciate the color.

Your next question comes from the line of Ole Slorer from Morgan Stanley. Please go ahead. Ole Slorer - Morgan Stanley: Thank you. First of all, congrats on your decision to return a greater part of cash flow to shareholders. I think there is a very clear difference at the moment in this evaluation of companies who do that and those who don't in this slower growth environment that they are in. First of all what were the biggest technologies that drove your share gains?

In terms of specific technologies, let me elevate it and maybe focus in on the product lines. So I would still say we have gained more share in wireline and drilling and measurements. Those are the kind of spearheading segment for these efforts, right. So there is number of new technologies that we have introduced in both these product lines over the past year or two and the uptake of them is good. What we also find now, as you know, we have restructured our engineering manufacturing into same organization about five years ago and this is really starting to pay dividends now because the new technology that comes out, it's performing much better than the initial technologies that came out five or ten years ago. There were lot more teething problems, which we are basically now avoiding. So, the new technology, which is commercialized within its first year, is actually now growing significantly faster than what it did may be five or ten years ago. So, I would say, wireline and drilling and measurements are still the ones again that are gaining the most share. Ole Slorer - Morgan Stanley: So it is then fair to say that this is largely driven by offshore?

No I think, it's both on land and offshore. Ole Slorer - Morgan Stanley: Okay, and a follow-up question would be, what market share changes are you seeing in the offshore market? One of your largest competitors continuously make claims that they are gaining share across all kind of (inaudible) technologies?

Well, I don't know who they are gaining share from, because it isn’t us. So I think, we are in the offshore market we obviously already have a quite a high share, but we reference Gulf of Mexico in some of these discussions and we continue to gain share in the Gulf of Mexico and in several of our high end product lines. Ole Slorer - Morgan Stanley: Okay. Just finally, how far away do you think from being a new pricing cycle in North America pressure pumping?

Well, I would say there is still significant overcapacity horsepower in the sitting on the sides today, so I don't see that happening in 2013, at least. I think, we are still going to have overcapacity as we exit this year. Ole Slorer - Morgan Stanley: Finally, what are some of technologies that are reducing the pressure pumping in tentatively of shale oil and gas in North America?

What technologies do that? Ole Slorer - Morgan Stanley: Yes.

Well, HiWAY is obviously one of them. We use significantly [less] and also generally less water in the operations that we do with HiWAY. The other way of reducing or lowering the intensity of these operations is to use much more of the subsurface approach prior to actually designing the jobs, right? So, having a much better understanding of the subsurface will allow you to design the completion of the well and the amount of horsepower water and pump use by be more selective in which stages you frac and also using more sophisticated frac fluids like HiWAY. Ole Slorer - Morgan Stanley: Are you seeing a change in attitude there with the shale oil gain becoming more and more of a large company gain?

Not a dramatic change, but I would say we have. We are starting to get several key customers that we are collaborating much closer with than what we've done in the past and where we engage all the way from characterization to drilling and production and taking a much more sophisticated approach to how we go about working with them on their developments, right? So, it's still relatively slow, but through some of the contracts we won over the past 12 months to 18 months, we have established as part of those contracts, a very strong technical collaboration agreements, which are also benefiting technology penetration. Ole Slorer - Morgan Stanley: So, on Forest Oil, the contract being in Eagle Ford, how would you characterize that in the context of just that?

Well, I can't really comment on that. Forest will release their results I think in a couple of weeks. We'd need to refer you to them.

Your next question comes from the line of Michael LaMotte from Guggenheim. Please go ahead. Michael LaMotte - Guggenheim: Thanks and good afternoon, guys. I wanted to just follow up on the North American onshore market and a little bit on the Forest Oil as well as Spark. Let me ask the questions just from the context of shift in business model in North America. I think both with Forest as well as Spark, you've tried to introduce a new model to the U.S. land market and I was just wondering now as you've been out marketing concepts like that for a while what the perception has been and what you think the uptake and penetration rate might look like?

On Spark, we are seeing a reasonable uptake on it. Nothing dramatic which we weren't expecting either. It's mainly focused on customers that are have vertically integrated. They have their own horsepower with very limited capabilities in terms of pumping more sophisticated fluid systems, so we continue to do Spark-related activity, but it isn't a significant part of our business which weren't really expecting either, but it's progressed reasonably well and we are happy with the performance from this. We are mainly doing Spark in North America, but we are also doing Spark in China for some of the frac operations there. The other part of your question in terms of the Forest Oil type of deal, initially as we said when we closed the Forest deal, our main motivation for doing that type of a deal was actually to get a display window for our shale technology capabilities, so we haven't really been actively out promoting SPM or production incentive type of contracts in North America, beyond trying to get that deal done, so we could demonstrate our capabilities for the technologies that we have developed. So, we know other progress or we haven't really even been pushing that model beyond that one deal we struck.

Your next question comes from the line of Bill Sanchez from Howard Weil. Please go ahead. Bill Sanchez - Howard Weil: Thanks. Good morning. Paal, two questions, one, I wanted to follow up on just how things are progressing on the SPM side. In the first quarter, you mentioned you had 10 projects. Goal was that two to three a year. I didn't see anything in the press release with regards to another announcement there. Perhaps if you could just update us on your thoughts? And maybe perhaps your size for us on a revenue basis annually? What SPM is going to contributing to the top-line for Schlumberger?

Yes, you are correct. We didn't sign any SPM projects in the second quarter. Our goal of adding two to three projects a year basically stands firm. But again, as I mentioned on my comments on the Mexico bid round, we will only sign the project that we believe are right for us. This is all about portfolio management. It is about picking the right projects, the right fields with the right terms and we have very stringent return criterias in terms of what we will engage in. So, our goal is two to three deal. If we can get the right ones, we will do it and if we can't find the right ones we won't do it. In terms of the impact on the business, it's still relatively a small part of our overall revenue stream, but by picking the right project it is a highly accretive part of our revenue stream and we will continue to focus in on maintaining it as highly accretive. Bill Sanchez - Howard Weil: Right. Your view has been that these projects are accretive to margins and essentially every geo market in which you have rolled it out. Is that correct?

That is correct. Bill Sanchez - Howard Weil: Okay, great. Well, my second question was just a follow up on North America margins, specifically as it relates to Geco which was called out in the press release but you didn't you specify, perhaps I missed it in earlier comments, whether or not Geco really was being driven in the Gulf, more by the Marine side of the business or whether we saw multiclient or maybe a combination of both? Then maybe just address Gulf of Mexico Geco as we think about the balance of '13?

Well, in the Gulf, in terms of ongoing operations, we have one Dual Coil fleet operating. It continues to operate in the Central Gulf. It has got a good backlog of things to do there on the multiclient site acquisition. We have an ongoing multiclient late sales business where we had some revenue progression which is seasonal basically from Q1 to Q2. We don't break up what that revenue progression was in a multiclient. You can see what the total is. The total for Q2 worldwide was $250 million, up from $175 million in Q1. So a part of that was North America, but I would say as the general comment on the multiclient performance in North America in Q2, it was below our expectations. We were expecting more sales to multiclient than what we actually realized. In addition to the multiclient business in terms of late sales and acquisition in the Gulf of Mexico we also started of the third-party survey offshore Eastern Canada and this is with isometrics. So those are basically the WesternGeco business in North America. Bill Sanchez - Howard Weil: All right. That sounds like that continues in second half of the year should be accretive to overall North America margins?

They should. Bill Sanchez - Howard Weil: Okay. Thanks, Paal, for the time.

Your next question comes from the line of Angie Sedita from UBS. Please go ahead. Angie Sedita - UBS: Good morning, guys or good afternoon and it hasn't been said. So I will say, congratulations on a great quarter. Very impressive of you and the team.

Thank you.

Thank you. Angie Sedita - UBS: On Mexico, Paal, I appreciate the color on the production of incentive contracts and the bidding there, but your thoughts on, I believe the next round of awards will be IPM potentially as much I have heard as $8 billion to $10 billion in contracts. You view that as the better and more attractive opportunity in the region and then along with that, have you had conversations with Pemex on the potential timing and is it multi-year for Mexico to open up and the opportunities there?

So what we know about the bids coming out is that there are a series of bids. So probably there would be a single service bids, there would be IPM well construction bids and there will probably be more production incentive type of bids coming out as well over the next couple of quarters. So, as I said earlier, we are very interested in the Mexican market. It is going to be very highly competitive. It has always been highly competitive but it's about, as I said before, being able to bid strategically, trying to pick up the right contracts and the right opportunities and having a plan for how you would create value for Pemex and at the same time create value for Schlumberger as we engage in these contracts, right. So I gave you a quick summary of our view on the third run of the FDM contracts and we will continue to evaluate every opportunity for gaining more work in Mexico and will engage in it with a view to make returns for the Schlumberger shareholders. Angie Sedita - UBS: All right. Then on the U.S. market, thoughts on the pace of activities for Q3 and Q4, are you seeing based on your conversations with the customers still steadily higher in Q3 as far as activity and Q4, the seasonal decline or are we going to run into the spent budgets that we did last year?

Well, whether Q4 is going to see the same as last year, I think it's just too early to say. Obviously, as WTI ticking up a little bit over the past month or so could be a positive preventing that from happening, but I still think it's too early to say what will happen in Q4. Our overview on the second half of the year U.S. land is, I think rig count is going to remain relatively flattish, but drilling efficiency is going to be the main activity driver, again generating reasonable growth in stage count, sequentially. Looking at Canada, we expect the H2 rig count at this stage to come in or the recovery in the H2 rig count to come in lower than 2012. While the stage can be expect to be more or less flat with last year. Then, again, continued strong activity in terms of offshore Gulf of Mexico, both shales and deepwater. Angie Sedita - UBS: Then finally you mentioned Russia being one of your strongest geo markets in 2013, is that in part driven by the Eurasia deal, or is it outside of that project?

Well, the Eurasia deal is part of our business and it's important part of our business in Russia, but it is only part of it. We have significant other activities both, on land and offshore both, in Sakhalin, in the Caspian, in the Barents, in the Arctic, so we are very well diversified in terms of both, customers and regions that we operate in Russia and that's why I think we manage to sustain very high growth rates.

Your next question comes from the line Jim Crandell from Cohen. Please go ahead. Jim Crandell - Cohen: Paal, one of your competitors was indicating in the marine seismic business relative softness in bidding activity for the fall winter season. What are you seeing in the fall winter season relative to the spring summer season and how does pricing look for that season right now?

For the marine market, we maintain our positive outlook, which we have basically conveyed over the past couple of quarters, right? The way we see its supply and demand appears to be relatively well balanced. In terms of bookings for Q3, we are basically already fully booked, and also Q4 in terms of backlog is filling up quite well. So, activity wise, things are looking quite good for us. In terms of pricing, in the second quarter, we didn't see any significant further traction in terms of basic bid pricing, but we also track another pricing indicator, which is revenue per streamer and our revenue per streamer was up about 10%, sequentially, and that's mainly at the backend of new technology and the type of service we conduct and also some seasonality effect. That's basically where we stand. Jim Crandell - Cohen: Good. That's helpful. And, one follow-up question about WesternGeco, when you used to break it out, this would of course be obvious, but could you give some indication where margins are relative to let's say the oil service average at WesternGeco, and I am just trying to handle on how much margin leverage there was there going forward?

We are not breaking out about any individual product line is doing in terms of margins. I can't really comment on that, but given where pricing stands and given the very significant new technology portfolio, we have and just putting into operation both, on land in terms of processing as well as marine, we obviously see margin upside potential for WesternGeco.

And, we have time for one further question today. That question comes from the line of Jeff Tillery from Tudor, Pickering. Please go ahead. Jeff Tillery - Tudor, Pickering: One of my questions I have is around the U.S. land business. You mentioned improved well service and pressure pumping utilization several times in the release. What are your thoughts around bringing some of the never deployed equipment in to the market given where your margins are? How do you see that as an opportunity in the second half of the year?

So we will look at bringing equipment in from what we have apart when we can get the utilization that we require for the overall group and at this stage we are not looking to bring anything back in that we have parked and I don't expect that to happen in 2013. Jeff Tillery - Tudor, Pickering: Great, thank you. Then my last question is just around the reservoir characterization business. With the significant margins increase there, I mean obviously multiclient helps, but if I look back historically there doesn't really tends to be a follow-up in multiclient sales in the third and fourth quarter relative to the second quarter. So any reason we should think about margins perhaps stepping backwards in the Reservoir Characterization business in the second half of the year?

No, nothing fundamental. This is a huge business and there are mixed effects depending on what region grows and there is exploration and development type of mixes even in characterization, but overall I expect the Characterization Group to continue to post very strong margins. Jeff Tillery - Tudor, Pickering: All right, thank you guys very much.

Thank you. Okay, on behalf of Schlumberger management team, I would like to thank you for participating in today's call. Greg will now provide the closing comments.

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