Ladies and gentlemen, thank you for standing by, and welcome to Halliburton's first quarter 2021 earnings call. Please be advised that today's conference is being recorded. I would now like to hand the conference over to Abu Zeya, Head of Investor Relations. Please go ahead, sir. Good morning, and welcome to the Halliburton first quarter 2021 conference call. As a reminder, today's call is being webcast, and a replay will be available on Halliburton's website for seven days. Joining me today are Jeff Miller, Chairman, President, and CEO, and Lance Loeffler, CFO. Some of our comments today may include forward-looking statements reflecting Halliburton's views about future events. These matters involve risks and uncertainties that could cause our actual results to materially differ from our forward-looking statements. These risks are discussed in Halliburton's Form 10-K for the year ended December 31st, 2020, recent current reports on Form 8-K, and other Securities and Exchange Commission filings. We undertake no obligation to revise or update publicly any forward-looking statements for any reason. Our comments today also include non-GAAP financial measures that exclude the impact of impairments, asset dispositions, and other charges. Beginning this quarter, we have modified our free cash flow metric, a non-GAAP financial measure, to include the impact of proceeds from sales of property, plant, and equipment. We believe this item is recurring in nature, and including it improves comparability of this metric relative to our large cap peers. Additional details, including recalculation of this measure for prior periods and reconciliation to the most directly comparable GAAP financial measures, are included in our first quarter earnings release and can also be found in the quarterly results and presentation section of our website. After our prepared remarks, we ask you to please limit yourself to one question and one related follow-up during the Q and A period to allow time for others who may be in the queue. Now, I'll turn the call over to Jeff. Thank you, Abu, and good morning, everyone. We're off to a good start this year. The world is reopening, and even though some regions still experience lockdowns, overall economic and demand recovery continues to build. Oil demand is increasing globally. Oil inventories are down near their five-year averages, and OPEC+ actions continue to support commodity prices. The first quarter strengthened our confidence about how this transition year will play out. Our first quarter performance demonstrates the strength of our strategy and operating leverage in this global market recovery. Here are some highlights. International revenue grew 2% compared to the fourth quarter of 2020, marking an activity inflection in the international markets. Strong recovery in Latin America more than offset declines in other regions, while margins remained resilient. North America revenue grew 13% as both drilling and completions activity ramped up throughout the quarter. Higher utilization and our significant operating leverage supported sequential margin expansion despite weather disruptions. Our Completion and Production division revenue grew 3%, with increased North America and Latin America activity offsetting seasonal declines in other regions. Our Drilling and Evaluation division delivered solid revenue and margin performance. Revenue grew 11%, while margins increased 2.6 percentage points, driven by stronger drilling activity in North America and software sales across multiple regions. Finally, we delivered approximately $160 million of free cash flow in the first quarter, which is a great first step to delivering strong free cash flow for the full year. This was another quarter of solid execution on our five strategic priorities that define Halliburton's path and will drive our success. We're committed to drive profitable growth internationally, maximize value in North America, accelerate and integrate digital technologies, improve capital efficiency, and actively participate in advancing cleaner, affordable energy. Our first quarter performance demonstrated that aligning our actions with these strategic priorities boosts our returns and free cash flow generation. We expect to continue delivering strong free cash flow and industry-leading returns as we move through the year. We are encouraged by the inflection in international activity we saw during the first quarter and anticipate that recovery will gain momentum across all regions in the second quarter and beyond. Today, we see early indicators of future activity growth internationally. Our completion tool orders, a leading indicator of upcoming work, grew throughout the first quarter. The volume of tendered work has significantly increased. We're on pace to nearly double the value of submitted bids compared to last year, with the most work coming from the NOCs in the Middle East, followed by Latin America. These signs give us greater conviction that the second half of this year will see a low double-digit increase in international activity year-on-year. We believe the international markets will experience multiple years of growth. This upcycle is expected to be structurally different from prior cycles, and Halliburton's international business is better prepared to benefit from it. Here's why. We expect the NOCs and other short cycle barrel producers will increase investments and gain share to meet future oil demand growth. Halliburton has the established footprint and the customer relationships to capitalize on this growth. As fields become smaller and more complex, operators work harder to produce more barrels. Their pursuit of incremental production to meet future oil demand growth should require higher service intensity. In certain markets, maturing assets are changing hands. New owners require proven technology and experience to revitalize their assets and unlock remaining reserves. Halliburton's broad technology portfolio, local expertise, and commercial flexibility are helping these customers achieve their efficiencies and production objectives. Multiple years of service company CapEx reductions limit equipment availability in the international markets. In early 2020, pre-COVID, international pricing was beginning to increase on the back of equipment tightness, but paused with the oil demand collapse. As the world reopens and activity rebounds, we expect large tenders to remain competitive, but leading-edge pricing should increase. Our strategic priority is clear: deliver profitable growth as the expected international recovery unfolds. We believe the following factors will help us accomplish this. First, we expect our ongoing investment in technology innovations to benefit us as the market recovers. For example, as the global leader in completions technology, we introduced the Ovidius expanding isolation packer. Ovidius uses material science innovation to transform a metal alloy into a rock-like material when it reacts with downhole fluids. It creates a long-lasting seal for improved well integrity and is especially suited for high-pressure and high-temperature environments, as well as permanent plug and abandonment operations. Our completion tools R&D pipeline incorporates the latest advancements in material science, sensors, telemetry, and digitalization. Ovidius is one good example of this pipeline. The successful rollout of our iCruise intelligent drilling system continues to deliver excellent results. In the first quarter, iCruise improved drilling speeds 55% for a customer in the Middle East, saved an operator three days of rig time in the North Sea, and increased drilling rates 25% compared to offset wells in offshore China. Second, our production business continues to expand internationally with unique growth opportunities. We plan to start executing on our first multi-year electric submersible pump contract in the Middle East in the second half of this year. We see significant volume and future growth potential for artificial lift solutions in the Middle East as many mature fields across the region come off natural flow and require ESPs to sustain production. With proven Summit ESP technology, a strong local presence, and a focus on profitable growth, we expect to thrive in this market. As we progress towards completing our specialty chemicals plant in Saudi Arabia, we are actively participating in regional tendering activity. In addition to providing new business opportunities, this plant will also manufacture chemicals for our internal consumption. We expect the new plant to deliver cost savings and profitable growth for Halliburton in 2022 and beyond. Finally, we are accelerating the deployment and integration of digital technologies with our customers. We believe digital creates technological differentiation, contributes to higher international margins, and drives internal efficiencies. In the first quarter, we introduced a new real-time data transmission system for a major customer in the North Sea. This high-fidelity, low-latency data highway is an essential building block for virtual remote operations that are performed without human intervention and use real-time data and tailored algorithms. We also launched a new digital workflow on a private cloud for an integrated services contract in the Middle East. This workflow helps our employees make better decisions. It uses a proprietary natural language processing service to extract specific information from a variety of documents and locate associated data in our data lake. This is digital technology in action, facilitating collaboration and knowledge management while improving operational efficiencies. These digital technologies are important milestones in our journey from digital planning to virtual execution. We're using our open architecture platform to integrate real-time information from the customer, Halliburton's many digitally enabled technologies, and third-party providers across the entire asset. I believe that Halliburton's current strengths and new capabilities will deliver profitable growth in a multi-year international recovery. Today, North America is staging a healthy recovery. In the current oil price environment, shale operators have a larger portfolio of economically viable projects. As a result, the average U.S. land rig count grew 27% sequentially in the first quarter, outpacing the growth in completed stages. What we are seeing today solidifies our confidence in a steady activity cadence for the rest of the year as operators work to maintain their productive capacity. The market dynamics continue to improve. Supportive commodity prices should allow our customers to spend their announced budgets and meet their cash flow objectives. Customer mix should transition as the year unfolds. Privates led the recovery in the first half, and we expect some public companies to increase activity in the second half of the year. Halliburton serves both of these customer groups, aligning with operators that have longer-term and more efficient programs. As a result, demand for our equipment is increasing and our calendar is filling up for the rest of the year. Last year, we used digital technology to redesign our service delivery approach and create significant differentiation in our cost structure. Adding to our cost reset in 2020, we continue to drive cost out of our North America operations. As an example, we've engaged with Vorto, a software company that designed an artificial intelligence supply chain platform to transform how we buy, move, and sell sand and trucking within our U.S. land operations. Without human intervention, Vorto's platform optimizes thousands of logistics loads per day, while also identifying and addressing issues before they occur. This fits with our strategic priorities to use digital technology to drive down costs in our business and to maximize value in North America. Together with our size and scale, our sustainable operating leverage should widen our margin differential relative to our competitors in North America. We are steadily improving margins, and our first quarter performance was another step in the right direction. As we look ahead, we see upside to our margin performance based on utilization, technology, innovation, and pricing. Utilization is the first step to better margins. With a smaller equipment base and the right customer alignment, we intend to continue optimizing utilization as market demand grows. Given our scale, the operating leverage impact from utilization increases alone should improve our cash flow generation in North America. Technological differentiation and digital innovation is the next step. Halliburton has the leading low-emission solutions in the market today, both electric and dual fuel, and we expect they will command a premium as market demand expands. As the leader in hydraulic fracturing, Halliburton has the scale and R&D depth to deliver a proven power agnostic, capital-efficient solution for e-frac. Deployed in the Permian Basin, our fully integrated all-electric frac site includes our 5,000 horsepower ZEUS electric pumping unit, our new ExpressBlend blending system, eWinch electric wire line unit, and the electric Tech Command Center. Built using our flagship Q10 pumps, ZEUS delivers performance levels up to 40% higher than conventional pumps and substantially reduces emissions limited only by the grid power source. As certain components of our input costs rise, we are working with our suppliers and our customers to adjust our gross pricing in line with cost inflation we are seeing in the market. While improving U.S. economic activity and winter weather disruptions led to increases in sand, chemicals, cement additives, and raw materials costs, Halliburton's purchasing power and technology have allowed us to procure and deliver these materials in a cost-efficient manner, such that both Halliburton and our customers are more competitive. Service pricing improvement is the final step. We're not there yet, but we see positive signs of market rebalancing that should drive future pricing improvements. Total fracturing equipment capacity has limited room to grow in the current pricing environment. Continued attrition from rising service intensity and insufficient returns for many service companies is altering the industry dynamics. Because we are an integrated provider, Halliburton participates in all key businesses in North America today and will benefit more than others when pricing moves up. We believe that Halliburton's leadership and strength in North America will allow us to take advantage of positive market dynamics and deliver on our strategic priority to maximize value in this market. Consistent with our strategy, we continue to turn every knob to manage greater capital efficiency and drive solid free cash flow generation. This takes many forms and includes important technology advancements in multiple product service lines, whether digital or equipment related, process changes that improve the speed with which we move equipment and respond to market opportunities, and finally, actions to reduce the pace of working capital consumption required to grow our business. The first quarter was a good demonstration of this, and we will continue to build on these actions. We're also executing on our strategic priority to advance cleaner, affordable energy and to support sustainable energy advancements using innovation and technology to reduce the environmental impact of producing oil and gas. Halliburton has a three-pronged approach to achieving this objective. First, we recently released our target to achieve 40% reduction in Scope 1 and 2 emissions by 2035 from the 2018 baseline. This is consistent with our goal to reduce the carbon footprint and environmental impact of our operations and follows our commitment to set science-based targets announced last year. Second, we're innovating. We continue to develop and deploy low-carbon solutions to help oil and gas operators lower their current emissions profiles. We also use our existing technologies in renewable energy applications. For example, today, the geothermal market in Europe is growing rapidly and represents an attractive expansion opportunity for our artificial lift business. We're currently supplying electric submersible pumps specifically designed for the high temperature, large wellbore applications on a geothermal project in Germany. We're also providing drilling and cementing services for geothermal wells in Indonesia. We developed new high-temperature cementing formulations and directional drilling techniques that increase geothermal sites' generating capacity and improve project economics. Finally, we're excited about the progress of Halliburton Labs, our clean energy accelerator. In the first quarter, we announced Halliburton Labs' inaugural group of participating companies. They're working on solutions for transforming organic and plastic waste to renewable power, recycling of lithium-ion batteries, and converting carbon dioxide, water, and renewable electricity into a hydrogen-rich platform chemical. We are collaborating with these companies and providing world-class industrial capabilities and expertise to help them achieve further scale and increase their valuations. This engagement in the clean energy space will inform Halliburton's future strategic decisions as the energy transition evolves. We are taking applications for the next cohort of participants as we continue bringing early-stage clean energy companies into Halliburton Labs. To sum up, we enter 2021 optimistic and focused on innovation. We believe that the early positive momentum in North America will continue, and the international market recovery will accelerate in the second half of the year. Halliburton will continue to execute on our key strategic priorities to deliver industry-leading returns and solid free cash flow as the anticipated multi-year recovery unfolds. I will now turn the call over to Lance to provide more details on our financial results. Lance? Thank you, Jeff. Let's begin this morning with an overview of our first quarter results compared to the fourth quarter of 2020. Total company revenue for the quarter was $3.5 billion, an increase of 7%, and our operating income was $370 million, an increase of 6% compared to the adjusted operating income of $350 million in the fourth quarter of 2020. Now, let me take a moment to discuss our divisional results in a little bit more detail. In our Completion and Production division, revenue was $1.9 billion, or an increase of 3%, while operating income was $252 million, representing a decrease of 11%. The increase in revenue was primarily driven by higher stimulation and artificial lift activity in North America, higher cementing activity in the North Sea, as well as improved stimulation activity in Argentina and Mexico, and higher completion tool sales in Latin America. These increases were partially offset by lower cementing services in Russia, lower pressure pumping activity in the Middle East, reduced seasonal completion tool sales, and lower well intervention services in the Eastern Hemisphere. Operating income was negatively impacted primarily by decreased completion tool sales and reduced pressure pumping activity in the Eastern Hemisphere. Our Drilling and Evaluation revenue was $1.6 billion, or an increase of 11%, while operating income was $171 million, an increase of 46%. These increases were primarily due to higher software sales globally, improved drilling-related services, and wireline activity in the Western Hemisphere and Norway, and increased project management activity internationally. Partially offsetting these increases were lower drilling-related services across Asia. Moving on to our geographical results. In North America, revenue was $1.4 billion, representing an increase of 13%. These results were primarily driven by higher drilling-related services, stimulation, and artificial lift activity in North America Land, as well as higher wireline activity and software sales in North America Land and the Gulf of Mexico. Partially offsetting these increases were reduced completion tool sales and lower cementing and fluids activity in the Gulf of Mexico. Moving to Latin America, revenue was $535 million, representing an increase of 26%, resulting primarily from increased activity in multiple product service lines in Argentina and Mexico, as well as higher fluid services in the Caribbean. Partially offsetting these improvements was reduced activity across multiple product service lines in Colombia. Turning to Europe, Africa, CIS, revenue was $634 million, a 1% decrease sequentially, resulting mainly from reduced completion tool sales and well intervention services across the region, coupled with lower activity in Russia and lower fluid services in Kazakhstan. These decreases were partially offset by higher well construction activity in the North Sea and increased software sales across the region. In Middle East/Asia, revenue was $878 million, or a 6% decrease. These results were primarily driven by lower stimulation and well intervention services in the Middle East, reduced drilling-related activity in Indonesia and China, and lower completion tool sales across the region. Partially offsetting these declines were improved project management activity in Iraq and Saudi Arabia, and higher wireline activity across Asia. In the first quarter, our corporate expense totaled $53 million. Looking ahead to the second quarter, we anticipate corporate expense to be slightly higher. Net interest expense for the quarter was $125 million, and we expect this level of interest expense to drift slightly lower in the second quarter as a result of our reduced debt balance. Our effective tax rate for the first quarter was approximately 23%. As we go forward into 2021, based on the anticipated market environment and our expected geographic earnings mix, we expect our full year effective tax rate to be approximately 25%. Turning to cash flow. We generated $203 million of cash from operations during the first quarter, and $157 million of free cash flow. We also repaid $188 million in maturing debt with cash on hand in the first quarter, and will continue to prioritize reducing leverage in the near term. Capital expenditures during the quarter came in at $104 million. We expect capital equipment deliveries for international projects to ramp up in the second half of the year, and as a result, our full year 2021 CapEx guidance remains unchanged. Finally, turning to our near-term operational outlook, let me provide you with some comments on how we see the second quarter unfolding. In North America, we expect both completions and drilling activity momentum to continue, but sequential activity growth should moderate. In the international markets, we expect a seasonal rebound and a broad-based activity increase, the pace of which will vary across different regions. As a result, for our Completion and Production division, we anticipate low double-digit revenue growth sequentially, with margins expected to expand by 125 to 150 basis points as a result of our strong operating leverage across all markets. In our Drilling and Evaluation division, we anticipate a mid-single-digit revenue increase, with margins declining 100 to 125 basis points sequentially. The moderate growth and anticipated reduction in margins are primarily attributed to the seasonal decline in our software sales globally. I'll now turn the call back over to Jeff. Jeff? Thanks, Lance. To sum up, I'm optimistic about how this transition year is shaping up. The demand outlook continues to improve both internationally and domestically, even as some regions still experience lockdowns. This year's headed in the right direction, and Halliburton is focused on the right things to deliver on our shareholders' objectives. We expect our strong international business to continue its profitable growth as activity increases throughout the year. In North America, our business has recovered and is demonstrating margin improvement on the back of our strong operating leverage. Digital is growing our revenue and helping us and our customers increase operational efficiency and reduce costs. Our commitment to capital efficiency is expected to support growth and solid free cash flow generation. Finally, we believe that our strategy to advance cleaner, affordable energy positions us well for the future. Now, let's open it up for questions. If you would like to ask a question at this time, please press the star then the number one key on your touch-tone telephone. To withdraw your question, press the pound key. Our first question comes from James West with Evercore ISI. Hi, guys. Morning, James. Jeff, clearly, international looks good in the back half. We're 90 days from your last conference call, and obviously you and I have spoken several times in between, but your visibility on the second half and even more so on 2022, which I think is more important, should've increased at this point. I'd love to hear your thoughts on kind of how the international recovery takes shape. I understand double digits year-over-year, second half of this year, but really as it kind of runs into 2022, how we should be thinking about regions, markets, where the growth is gonna be, and should that double-digit momentum continue? Yeah. Thanks, James. Yes, confidence improving, and visibility improving around our outlook, both for 2021 and for 2022. In fact, when I see tender pipeline strong, strengthening, these are all sort of the things that start sometime later this year, but really start to get traction in 2022 and even 2023. Some of the programs that we're seeing are shorter cycle barrels. The fact is, those are actually service intense barrels to find, so which means it's going to drive. Right. More upstream spending faster. Even if I look at just 2021, outlook confidence is more so today. I think we see it at a minimum improving to flat year-on-year, which is an improvement from what we thought earlier. Right. Okay. Makes sense. As we think about North America, obviously the big E&Ps are gonna remain capital disciplined and probably show some really good cash flow this year, given where the oil price is. They'll step up next year, as they've committed to spend a certain% of cash flow. Are you starting to have conversations or starting to think about 2022 as it reflects to North America, and kind of what the increase could be in spending if oil prices are 30% higher than they were going into this year? Yeah, James, I think we're going to see sort of the steady cadence of increase, as we move through this year and even into next year. I think that just the feedback and sense I get is that there is a lot of discipline around production and what they can do profitably. Yeah, I also think as we see improvement into 2022, they will face service cost inflation just because of where everything is today. Right. Equipment needs to be replaced. It certainly won't be the same, and I think that tightening of capacity is very good for Halliburton, and I think that if anything, that'll be a bit of a governor. Got you. Okay. Thanks, Jeff. Thanks. Our next question comes from Scott Gruber with Citigroup. Jeff, good morning. Morning, Scott. As you guys probably heard in some of your investor conversations, there's been some concern around Halliburton in terms of C&P margins, as we start the year just given the mix towards the domestic completion market when we heard the 2Q guide, obviously. How should we be thinking about the second half? Assuming no net pricing in the U.S., with the international side starting to accelerate, U.S. continuing to expand on a more efficient and streamlined platform, how should we think about second half incrementals? What kind of from a high level if you could put some color around that? Can we do better than the 2Q pace, which looks like to be around 25%? Well, look, thanks, Scott. We're confident about the progression in North America, certainly for C&P and globally. I think that our goal is to maximize the value of this business. I've said I think could expect mid-teens full year, and I think that's a solid number, and that's reflecting an activity increase that is driving the incremental margins as opposed to pricing. No pricing in that. I think we have visibility towards what will drive pricing, which will substantially improve, in fact, supercharge those incrementals. I think right now we're building our outlook around what is the steady cadence of improvement, and maintaining, actually continuing to drive further efficiencies in North America with respect to keeping our cost under the reset that we did last year is still alive and well and in place. Got you. A similar question on the D&E side. Obviously some noise on the margin front around the software sales. Maybe some color on the second half for D&E. I guess the question is, in the past, as we've seen the international side of the business accelerate off the bottom, we've often seen startup costs limit the margin improvement potential at least for a couple of quarters at the start of the cycle. Is there a risk of that this cycle, or is that really diminished given the digital applications and streamlining the platform? How should we think about D&E margin expansion in the second half as things start to pick up internationally? Yeah, thanks. Look, I think the D&E starting at a higher point than it did finished last year is important. I think it says two important things. One, our software business is strong and accretive. It also says, though, that the rest of D&E's margins, the baseline is improving. We're knocking on double digits as we look out through the rest of the year. As I look at the back half or the international expansion on D&E, we're positioned today for that. The kind of investment we're making, we view it as a march. We want to continue to improve the baseline margins in that business so it's continuing to improve. I think we'll see improvement in 2021. I think that continues beyond that. Our outlook is for continuing to grow those margins. I don't see the kind of headwinds that we might've seen a year ago when we were ramping for one of the largest contracts in the North Sea. I don't see that repeat. Some of what we're getting also is the benefit of the capital efficiency that's baked into a lot of our D&E ability to move things around. In fact, at the core of our strategy is capital efficiency, and I think that manifests itself around how we move tools and other things. Great. Appreciate the color, Jeff. Thank you. Yeah. Our next question comes from David Anderson with Barclays. Hi, good morning, Jeff. I just wondered if you could just talk briefly about the pressure pumping market. Hearing a lot of talk about DGB engines and E&Ps increasingly looking to move away from diesel. Some reviews suggesting higher pricing on this type of equipment. I was just wondering if you could kind of tell us where you stand on this. Are your customers pushing for this type of equipment? Are you starting to see any bifurcation of the market on pricing because of this? Thanks, Dave. Look, I think as we look into the future, those types of solutions will get pricing earlier, and more so. We are seeing more demand for those types of solutions, and we have a leading position around whether it's Tier 4 dual fuel or also the electric. Yes, we're seeing the demand. I think that the bifurcation will happen gradually simply because of the ability to do two things. One, put equipment into the market, the way we look at that is that's replacement equipment generally. We've got 10%-12% of our equipment that goes off every year, what we're able to do is replace that with what we view would be higher margin, better returning equipment over time. That's more the pacing that we see. The other sort of key components around pricing, when we look at, and I won't get into all of this, but when we think about returns for new equipment, any kind of new equipment, but particularly technology, we expect some premium around the technology and also de-risking the time horizon impact of making those returns also. I think that's equally key. That makes sense. If I could just switch over to the international side. You talked about improved project management activity in Iraq and Saudi Arabia. I was just wondering, first, was there anything noteworthy behind this improvement, or is this more the course of business? Kind of more importantly, as you look at the tendering activity out there, is this going to be a preferred contracting model for NOCs? I guess assuming we're at the beginning of a multi-year growth phase, and if so, are you comfortable increasing your exposure to project management activity? To answer the first question, Dave, that was just sort of normal course of business. Okay. We see improvements and we see more activity at different times. That's really all to read through on that. I think with respect to project management broadly and how we see those contracts in the future, obviously a lot of activity around that. We'll be certainly very thoughtful around how we increase that exposure, we manage that risk. In fact, the most important component of looking at those types of things is understanding and managing the risk. Of course. It's one of the reasons I'm so, you hear me say it a lot, but I'm talking about profitable growth internationally. That profitable component's going to be the lead punch around how we grow internationally. Certainly we're in that business. We're good at that business. We're also pretty circumspect around how we make money doing that. Thanks, Jeff. Thank you. Our next question comes from Sean Meakim with JP Morgan. Thank you. Hey, good morning. Morning, Sean. C&P had a pretty good quarter, all things considered. You expected some mix shift for the back half of the year. Private E&Ps led the early recovery. You said you're expecting some publics to add rigs in the back half. Does this also suggest that you think private E&Ps have mostly added what they can under the current oil price environment? They're over half the rig count today. They're two-thirds of the rigs added off the trough. Their end market, their end economics are not that different maybe than from the publics. Just curious, your visibility on private E&P activity for the balance of the year. Yeah, look, I think that they're the most nimble group. They're going to move the quickest to engage. They also have the least impact on the overall headline production number also. I think that I really am encouraged by the activity that we've seen, the ability to continue that. I think they're all making their own economic decisions, and they make that really without a lot of stakeholder beyond the owners' direction. I think what we're seeing is a natural reaction to that, but I don't think it's indicative of how the whole market behaves, they have the ability to get real busy and then slow down and back it down as they see production start to ramp up a little bit for them, and it changes their economics. A hard march up into the right, not necessarily. I think they'll all make their own decisions and could easily, I'm not going to say back off, but what they will do is make those decisions as other operators start to ramp up, and that's obviously a much more disciplined group who have plans in place. I think the key point to make here, though, we're at the end of the first quarter, we're into Q2, and we haven't talked about any of the kind of budget blowouts that we talked about in prior years where you're like, "Oh, wow, we've overspent, so there's something coming that's going to slow things down." That's not at all what we see. In fact, what I'm describing in terms of confidence in the cadence is confidence in the cadence that we are going to stay busy in marching through the second half of the year, likely up some. In fact, I think our outlook today is up North America, maybe close to 10% on the full year. That's some moderation, but that's still growing. That's a good point. I appreciate that feedback. On D&E, the results were obviously impressive. We've sort of unpacked the impact of seasonal software sales spilling into the first quarter. You've also been press releasing a lot of the new contracts, and agreements tied to digital initiatives. I'm just curious how much of the confidence underlying your margin commentary is driven by the improved mix from digital, and could it eventually be justified to maybe enhance some disclosure around the materiality of digital to your results? Well, certainly, digital is enhancing our margins. That's certainly where we want to see that go, and we expect it to continue. It's also baked into all aspects of our business. From a digital perspective, it is equal parts customer-oriented, like just consulting and software sales. It's also equal parts making our tools better, so they become answer products, and we sell them through the normal course of business, but they meaningfully impact the value of those tools. Finally, what it does internally to drive our own cost down. Helping, yes. I think more importantly, when I look at D&E is, again, back to that baseline of improving margins, which is built on the back of the iCruise performance and technology there, wireline performance and technology there. Those kind of things that are operational, we can see them, we see them getting traction, more broad traction. Those are the kind of things that as we look into a multi-year upcycle internationally, that's what's going to drive margin up 2021, 2022, 2023. Really helpful. Thanks, Jeff. Our next question comes from Ian Macpherson with Simmons. Thanks. Good morning, guys. Jeff, I wanted to ask you for an update on your innovative frac operations. You spoke interestingly last quarter about SmartFleet, as well as we've seen what you've accomplished with the grid-powered fracturing. I know there's been some IP contests there. We don't need to talk about that, but just an update on how those operations on leading-edge technology and domestic frack are going and how you see that blossoming over the course of the year with incremental fleets of those varieties. Yeah, look, I really like the technology. I like what we've done. The SmartFleet is as advertised. We've got more trials to do, but we continue to find more effective ways to deliver that solution, which should allow it to scale even more quickly. I think it's going to continue to gain a lot of traction. Very capital efficient approach to implementing technology because it implements with the equipment that we have. From an e-fleet standpoint, again, certainly pleased with the performance that we've seen. Yes, it continues to drive or deliver on the kinds of efficiencies we thought we would see, both for us in terms of utilization and dollars per horsepower. Lot of interest from customers around that technology also. Let's remember we're maximizing value in North America, so we only put this equipment out when it meets our return expectations and we can de-risk the time horizon. It's going to look more like replacement of upgrading replacements as opposed to new investment. Understood. Thanks, Jeff. Separately, Lance, I wanted to ask you about the free cash flow progression going into Q2 and for the rest of the year. Obviously, the CapEx was light loaded in Q1. Just thoughts on how the CapEx sequences through the year and just general, maybe a refresh on total absolute dollar working capital framework for this year. Sorry, not working capital, but bottom line free cash. Yeah. No. Good question, Ian. Look, I think, overall, as everyone knows, maximizing free cash flow remains the key priority for us and what we're focused on. More so, free cash flow that's driven by margin progression and then all aspects of the capital efficiency. I know Jeff covered a little bit in his prepared remarks around efficiency and working capital, and remaining disciplined around CapEx. Look, more operating profit we see ahead, based on our activity outlook improving and obviously the progression around margins that we've discussed already this morning. We're pretty optimistic about what all of that means for 2021 free cash flow target, which today gives us more confidence that we will be ahead of where consensus sits today, even excluding the change in the metric that we've outlined this quarter. Perfect. Thanks, Lance. You bet, Ian. Our next question comes from Chase Mulvehill with Bank of America. Hey, good morning, everybody. Hey, good morning, Chase. Hey, Jeff. Hey, Lance. Hey, Jeff. I guess in your prepared remarks, you talked about a doubling of the value of submitted bids across the international market if we compare that to what you saw last year. I guess I was hoping that maybe you could provide a little color, relative to the mix between NOCs, IOCs, independent E&Ps and maybe the regions that you see the most pickup in bidding activity. I don't know if you'd be willing to step out over your skis a little bit and say what it might would mean for activity as we get into 2022 if you start signing a lot of these contracts. I know you talked about some continued growth and some strong growth on the international side over the medium term, but I don't know if you'd like to quantify that at this point, just given the bid activity you're seeing. Look, I think the type of activity we're seeing is probably more weighted towards Middle East, Latin America, broadly, in terms of tender activity. I think that I'm not going to try to quantify things that are too derivative, tender deviations in the future. What our view is, that's certainly indicative of a growing market and the kind of market that will grow over time. We're going to engage in that and participate in it, and be successful. Our view is, A, focus on profitable growth and drive international revenue growth that way. I think we're also going to see that sort of lead to the broader-based kind of recovery, which is equally important to price. I bring that up just to say that these big tenders are always very competitive from a price standpoint. Where we start to see price improvement, typically, is as the market sort of starts to fill up and we see more opportunities. That is how we see the international market shaping up. I think that's an equally important concept to what we're seeing in terms of growth. Okay. All right. Thanks for the color there. Maybe if I can kind of come back to the conversation around U.S. onshore and try to tease out a little bit more on the publics versus privates. I don't know if you'd kind of be willing to share your mix of publics versus privates on the U.S. onshore. I know kind of overall rig activity is roughly half between the publics and privates today. It continues to kind of see a shift towards privates as activity continues to rebound because they're obviously responding to a higher oil price while the publics are not. Maybe just talk to your mix and kind of what advantages you think you have, when you look to kind of pursue more opportunities on the private side versus your competitors. Look, we have a great footprint in North America. We've got a leading position in North America, which means we really work for all of the customers in North America. From a mix perspective, what we look for is efficiency, we look for opportunity, we look for growth opportunity, and we look for uptake on technology and performance. I think that's the way we view the market, less around A versus B, but it's more do they have the characteristics that allow us to drive our value proposition in the market and maximize the kind of returns like we're talking about. I think that that moves at different times, depending on where the market is. It doesn't usually change a whole lot. Okay. All righty. I'll turn it back over. Thanks, Jeff. Thank you. Our next question comes from Marc Bianchi with Cowen. Thank you. I guess thinking about the cost structure going forward, there's a few variables, I think, with COVID and normalization, hopefully, coming out of COVID, where maybe there could be some increased travel and entertainment expense. I'm curious how that sort of factors into the margin outlook that you have and if there's any risk to maybe a headwind to margin as we get into the back half of the year? Yeah, thanks. Look, those types of costs are in our outlook, so we manage cost all of the time. I don't see a bow wave of that coming back. We've reset the earnings. We reset it in terms of how we work and how we move people around and how we go to market. Look forward to the market opening. I think that's gonna drive a lot more demand. That'll continue to drive demand for oil. I think from our standpoint, we just manage those costs. Yep. Thanks for that, Jeff. Lance, back on the free cash flow, working cap was a positive number this quarter, there was another sort of $250 drag or outflow from other operating outflows. Could you talk about that? Just as I think about those two lines over the course of the year, would you expect them to be net neutral, positive, negative? Yeah. Other operating, in the cash flow line item tends to be pretty heavy in the first quarter. We've got compensation that tends to hit in the first quarter as well as taxes are heavy with property taxes, et cetera. That's not atypical from us from an intra-year cyclicality perspective. We expect that to lighten up, obviously, in 2Q. That's sort of the color I would give you on that. Okay. Thanks for that. Turn it back. Great. Thanks, Marc. Thank you. Our next question comes from Connor Lynagh with Morgan Stanley. Yeah, thank you. I was hoping we could put a finer point on some of the discussion on pricing in international. You've made the comment that obviously large tenders will be competitive, but leading-edge pricing should increase. Can you maybe frame for us the extent to which leading edge pricing is meaningfully different from what your more sort of contract book looks like. In other words, if leading edge pricing is moving higher, does that imply that contract pricing will follow, or is there a marks-to-market effect we should think about? No, I think contract pricing will follow, is the way that works generally. It starts there. The contracts themselves improve over time. I think that having alternatives that are higher priced also help to create pressure, upward pressure on pricing even in larger contracts. I would add, what Jeff is describing is exactly what we were seeing in the early part or late part of 2019 and 2020, was that dynamic in terms of large tenders still bid competitively, but rising level of activity was tightening the rest of the broader market. Obviously, we took a pause with COVID, but we expect as we see activity levels creep back to where we were at that period of time, I think we're optimistic that we start to see the same behavior from a pricing perspective. Got it. Makes sense. I guess just further to that, so on the large tender side of things, there's been some discussion about some of the softer elements maybe improving before pricing. How do you guys feel about the potential for terms and conditions or different types of ancillary charges improving in the near term? I guess the other question is, you've made a lot of changes to your cost structure. Do you think you can maybe drive improved margins without the increase in pricing? Yes. We expect to do that, and that's as we continue to see activity come on, we will see improving margins. Always working Ts and Cs. There are always leading edge sort of things that we're working on that become easier to do, become very important over time to do, and we're doing those all of the time, and we're doing those now. Also, digital sort of implicit through all of this, and we see our digital improving, driving margins better all of the time. I think we should see improving margins before we see even the pricing. I think the pricing is what allows us to really That's where we see the real traction in incrementals. Appreciate the color. Thanks. Our next question comes from Chris Foley with Wells Fargo. Thanks. Good morning. Just wanted to ask first on some of the cost inflation that was mentioned in the prepared remarks. Is that mostly getting offset in the pretty near term, maybe this quarter or next, or is there any impact that could be flowing through as you get price recovery in the second or third quarter? Just curious if there's going to be any tailwind from that. Yeah, Chris. This is Lance. Yeah, a lot of that's largely the cost inflation that we describe is driven by what's happening in North America and the growth that we're seeing there. Some of it was driven by the impact of the storms, right, and some of the shortages that we saw across the value chain. I would say, look, our size and scale gives us an inherent advantage to negotiate the best deals in a lot of those consumables. To the extent a lot of our commercial arrangements allow us to pass that through to the customer. Our guidance overall sort of incorporates that. I think, look, we're always going to be continuing to focus on maximizing our value in North America regardless of the challenges in the environment. That's sort of baked into how we see at least the near term playing out and obviously the outlook we've given for the year. Okay, thanks. That's helpful. Maybe on CapEx, I think in the past you said 5%-6% range. In the data it looks like service intensity is very high. Pricing has not really caught up with the amount of work that's getting done. Just curious to check in on the 5%-6% range, if you expect that would still be in place for 2021 and probably 2022 as well. Yes. Yeah, when we talk about capital efficiency and driving capital efficiency through all parts of our business, that's what allows us to get to that 5%-6% of revenues in terms of CapEx spend. Yes, for 2021 and 2022. Perfect. Thank you. Thanks. That concludes today's question and answer session. I'd like to turn the call back to Jeff Miller for closing remarks. Thank you, Liz. Before we end the call, I'd like to make a few closing comments. I am encouraged by this year's positive momentum and demand recovery. We are well-positioned globally for growing international demand, the expected steady activity cadence in North America, and with our leading digital technologies, which allow us to maximize value for Halliburton and its shareholders. Look forward to speaking with you again next quarter. Liz, please close out the call. Ladies and gentlemen, this concludes today's conference call. Thank you for participating. You may now disconnect.