Good day, ladies and gentlemen, and welcome to the NOV first quarter 2022 earnings conference call. At this time, all participants are in a listen-only mode. Later, we will conduct a question-and-answer session and instructions will follow at that time. If anyone should require assistance during the conference, please press star then zero on your touchtone telephone. As a reminder, this conference is being recorded. I would now like to introduce your host for today's conference, Mr. Blake McCarthy, Vice President of Corporate Development and Investor Relations. Sir, you may begin. Welcome, everyone, to NOV's first quarter 2022 earnings conference call. With me today are Clay Williams, our Chairman, President, and CEO, and Jose Bayardo, Senior Vice President and CFO. Before we begin, I would like to remind you that some of today's comments are forward-looking statements within the meaning of the federal securities laws. They involve risks and uncertainties, and actual results may differ materially. No one should assume these forward-looking statements remain valid later in the quarter or later in the year. For a more detailed discussion of the major risk factors affecting our business, please refer to our latest Forms 10-K and 10-Q filed with the Securities and Exchange Commission. Our comments also include non-GAAP measures. Reconciliations to the nearest corresponding GAAP measures are in our earnings release available on our website. On a U.S. GAAP basis for the first quarter of 2022, NOV reported revenues of $1.55 billion and a net loss of $50 million. Our use of the term EBITDA throughout this morning's call corresponds with the term adjusted EBITDA as defined in our earnings release. Later in the call, we will host a question-and-answer session. Please limit yourself to one question and one follow-up to permit more participation. Now, let me turn the call over to Clay. Thank you, Blake. For the first quarter of 2022, NOV's revenue of $1.548 billion grew 2% sequentially, and EBITDA increased $34 million to $103 million or 6.7% of revenue. Year-over-year revenues were up 24% at 34% leverage, reflecting positive impacts of aggressive cost reductions and some recent pricing recovery, offset by continued inflation and supply chain disruptions. Helped by continued high demand for offshore wind renewables, along with rising oil and gas demand, orders were strong across the board as we put up a consolidated book-to-bill of 115% in the first quarter. The organization's execution against shifting challenges in supply chain freight and labor improved during the first quarter, in part by broadening our base of suppliers as well as recovering escalating costs through higher pricing. Where costs for certain raw materials like resins appear to be easing, unfortunately, a lot of components got worse during the quarter. Steel forgings, polymers, fiberglass, electronics, stainless steel, and switchgear, most notably. Freight challenges intensified in the Eastern Hemisphere owing to the conflict in Ukraine and continued COVID impacts in the quarter. Recent standard cost rules on many of our products moved up materially, reflecting the higher costs we face. Thus, considering all these extraordinary challenges, we were pleased to see improved execution and better financial results for the quarter. While results are still below acceptable levels, our outlook is constructive given the steady tightening of oilfield services capacity that is driving accelerating demand for NOV's core oilfield products. This uplift is giving us improved line of sight towards healthier returns for our shareholders. For reasons I'll go into in just a moment, I believe this upcycle will last a while. First, however, I'd like to take a minute and speak to some oilfield fundamentals. Constructing an oil or gas well takes much more than good reservoir rocks and a drilling rig. Oil and gas companies rely on highly specialized geotechnical talent to identify and delineate drilling locations, and on petroleum and processing engineers who design wells, production systems, and processing and transportation facilities. The business requires investments in expensive leaseholds, wells, and fabrication of platforms, processing plants, gathering systems, and refineries that make oil and gas production one of the most capital-intensive industrial undertakings. The actual well construction is performed by oilfield service companies that, in turn, operate very expensive, highly engineered, fit-for-purpose equipment fleets, which probably make it the second most capital-intensive industrial undertaking around. All this plant, equipment, and well construction process utilizes a lot of steel as well as exotic metallurgies, polymers, resins, computer chips, electric motors, and electronics. The work is performed by hardscrabble men and women, from roughnecks to drillers to truck drivers, working long hours in remote locations for usually above average pay in tandem with talented geoscientists and engineers supporting these complex operations. One way to think about our industry is a finely tuned and optimized machine into which goes capital, a lot of capital, highly skilled engineering talent, hard work by experienced oil field hands, fertile acreage identified by geoscientists that holds the promise of profitable production, and a lot of highly spec'd pipe, plastics, engines, resins, and computer chips. Out of this oil and gas machine comes your high standard of living, the high standard of living that your family and my family and millions of others enjoy, along with the hope of a better standard of living for literally billions of people in lesser developed economies around the world. Out of this machine comes the food that we eat and the fertilizer made from natural gas that the farmer uses to achieve amazing agricultural productivity from fields plowed and harvested using diesel-powered equipment. All air travel, most transportation on demand, plus all ocean-going freight and rail that brings food and products into our lives. The plastics that doctors use to deliver our medical care, and a thousand other things that make our lives better. From construction to transportation, to petrochemicals, to pharmaceuticals, to consumer goods, to you name it, the oil and gas industry connects with and supports a hundred industries that form the foundation of our modern lives. This leads me to our current predicament. Two years ago, remarkably, we faced negative oil prices. Today, the world is confronting triple-digit crude prices and all-time high global natural gas prices. While this rapid shift is jarring and damaging to global economies, frankly, it should not have been entirely unexpected. For the past few years, governments and capital allocators have been playing a dangerous game with respect to energy and the global economy. While transition to lower carbon renewable sources of energy for the world is required for the long-term good of the planet. It seems we've gotten ahead of ourselves as we've attempted to pivot away from fossil fuels, which are inherently reliable and energy-dense sources of power, to lower density forms of energy with intermittency issues and inferior economic profiles. Prior pivots to new energy sources were accomplished over decades. Think about the shift from firewood to coal through the eighteenth and nineteenth centuries, the shift from coal to oil through the twentieth century, the emerging shift to natural gas over the past 25 years. These were driven by economics, superior energy density, and value for lower cost to supply rising per capita energy demand. Unfortunately, the lower carbon energy transition today lacks a robust economic engine driving it forward. While LCOEs have fallen for solar, wind, and other forms of renewable energy, I believe LCOEs will continue to fall through technical advancements that NRG and others are making. Renewables are still expensive and suffer from intermittency challenges that require storage solutions that add to their all-in costs, frequently not accounted for in LCOE calculations. To accelerate this transition in the absence of a compelling economic driver, governments, regulatory agencies, and media decided it would be a good idea to demonize the oil and gas industry. Let's be honest, you know what I'm talking about. I think the motives behind this are pretty evident to bring about the acceleration of a desired energy transition outcome, namely a more rapid pivot to renewables. Specifically, the oil and gas industry has been under attack by political, bureaucratic, and media leadership that have been very effective in choking off the inputs into the oil and gas machine I described earlier. Now let's turn back to those, starting with capital. Unrealistic near-term peak oil demand narratives built on the promise of rapid substitution of renewable energy have significantly dampened equity investor interest in oil and gas stocks, both in public markets, where energy weighting of the S&P 500 bottomed recently at less than 2% compared to 14% in 2008 and more than 20% in the 1970s, and in private equity. With little or no terminal value expectation due to a broadly accepted narrative that oil and gas goes away soon, it's easy to understand why equity investors have been reticent to invest here. With the relentlessly negative PR the industry receives, we understand why it's been fashionable for college endowments and other institutions to trump their divestitures out of the space. Meanwhile, commercial banks are being pressured by both their shareholders and regulators to trim lending to the sector. In short, capital in all forms has become way more expensive to oil and gas. Next, the industry needs engineering talent. Again, unrealistic peak demand scenarios and negative PR have frustrated efforts by the oil and gas industry to recruit young talented engineers who worry about investing their careers in a sunset industry. This recruiting effort is becoming more urgent as the industry needs to replace its experienced but aging baby boomer workforce soon, referred to by industry insiders as the great crew change. Oilfield work has provided high wages and high standards of living in small towns and remote areas for generations of blue-collar workers. It's not for the faint of heart. Deep, deep cyclicality requires painful, significant cuts during oilfield downturns, which can be brutal. As the U.S. rig count dropped to record low levels in the summer of 2020 following the global government decisions to shut down economies, the oilfield did the difficult task that we are unfortunately called to do from time to time. We laid off a lot of good employees. This was very, very tough on many good people and families, and they remember it. When we fast-forward to today, when the broad economy is growing, unemployment is low, attractive job opportunities are available outside the oil patch, and family balance sheets are in much better shape owing to the pandemic stimulus checks, it is extremely difficult to attract direct labor back to the oil patch, and frankly, it requires much higher wages. Oilfield services also cut investments in its hard assets. The downturn saw companies cannibalize underutilized oilfield equipment for spare parts rather than spend precious cash needed to survive on properly maintaining fleets required for more normal levels of activity. As industry activity ramps, oilfield service companies are swimming upstream against the congested supply chains as they scramble to put incremental equipment back in shape to work. The physical inputs required for these equipment overhauls, bearings and hoses, engines and transmissions, polymers and resins, chips and circuit boards are incredibly tight. While the U.S. is back to growing production off of 2020 lows by drawing down DUC inventories, we are the only such country that's growing. Global crude inventories are well below average and still trending the wrong direction because we are no longer the just-in-time industry we were in the prior decade. The oil and gas machine needs promising acreage as well. Our E&P customers tell us that the current regulatory environment continues to get more expensive and challenging, orchestrated, in their view, by agencies that are all trying to affect a more rapid energy transition, while in other developed countries, they faced outright bans on oil field activity. By the way, geoscientists need years to find and delineate fertile acres through exploration. Unfortunately, global exploration was severely cut following the downturn of 2015, meaning the pipeline of prospects to develop is very limited after seven years of underexploring. To summarize, when we survey the inputs required to construct oil and gas wells, from capital to labor to workable regulations to prospect development pipelines to engineering talent to consumables and equipment all face significant hurdles put in place by politicians, regulators, and media. My question is this. Has this been a good idea? Has it been a good policy to demonize the industry that quite literally powers all other industries? Political leaders across the globe have not been honest with voters and consumers about the cost, feasibility, difficulty, inconvenience, and time required to fully pivot to renewable sources of energy, in my view. I'm not questioning the need to make the pivot, but rather the plan to get there. The de facto policy of choking off inputs of a critical industry, not just years but decades before we have a good alternative, is a very bad policy. Many will suffer as a result. To make matters worse, the enormous economic stimulus that accompanied the forced shutdown of the global economy during the pandemic massively increased money supply across developed economies as governments printed money at a breathtaking rate. The US M2 money supply is up over 40%, for example. Historically, inflation rolls directly into commodity markets like oil and gas. This time, I believe it will be amplified by input constraints that I cataloged earlier. Add to this productivity gains from workforce demographics and globalization that offset money supply growth in prior generation that today are going the other direction, and it's no surprise that dollar inflation is at 40-year highs and rising. In summary, I could not have scripted a more compelling setup for an energy crisis. While this points to rising demand for equipment and services NOV brings to the oil patch over the coming quarters and years, it also points to a pretty dark view of economic challenges we face as we undo the mess created. The world now finds itself in critical need of an industry that it had written off as a sunset industry, and reconstructing this industry will not be easy. Seven years of E&P underinvestment of oilfield services, effectively dismantling much of its capacity and drastically shrinking its workforce in order to survive, together with the additional hurdles created by the vilification of oil and gas, make what is required out of this a very heavy lift. According to a recent research report, the industry halved its resource life since 2014, and fewer FIDs in recent years will potentially lead to approximately 10 million barrels of lost production by 2024. The prospect pipeline continues to shrink while ESG measures drive operating and financing costs higher. Skilled labor markets are tightening, and inflation and supply chain disruptions are pushing large project cost curves significantly above the levels seen in the prior decade. Accelerating global decline rates adds further risk of global production shortfalls. In order for the world to avoid an energy crisis, the likes of which we haven't seen since the 1970s, we need a synchronized global oil and gas supercycle of some duration, and we need it to start yesterday. We need, and thankfully, we are starting to see, both short-cycle shale oil and longer-cycle offshore development of petroleum resources. The low rates charged by oilfield service participants over the past several years did not reflect the physical consumption of capital equipment used in operations, much less earn a decent return for oilfield service shareholders. However, that overhang is diminishing rapidly and has been replaced with tightening schedules and lean, if not bare shelves. Pricing is beginning to move across the oilfield after years of service industry subsidizing its customers by cannibalizing its own capital base. While the moves thus far have been small, mainly to keep pace with inflation, our oilfield service customers report net pricing momentum is beginning to grow. Nevertheless, while all the foregoing is worrisome for the global economy, I am confident our company, our industry, and the producers we serve are up to the extraordinary task of growing production to provide energy security and better standards of living for humanity, just as we have done for 163 years. The oil field is nothing if not resourceful and resilient. Since 2014, our organization has shrunk dramatically to make it to the other side of this 7-year down cycle, but we never took our eye off the ball in technology development initiatives. NOV continues to invest in and lead in both oil and gas technologies, along with the emerging renewable technologies that we've spoken of through the downturn. While an energy transition to a lower carbon future is required, the world is finally waking up to the fact that oil and gas is still absolutely essential to our modern way of life, and the oil and gas industry is quickly becoming aware that it can't continue to meet the world's demand for its products without significant further investment. NOV is the enabler of what still is the most important industry in the world, and we stand ready to meet the challenges of the coming upcycle. To the employees of NOV who are listening today, thank you for all that you've accomplished through this tough, historic downturn. Your hard work and perseverance got us here. We have a lot more hard work ahead, and now it's showtime. The world will be counting on us. With that, I'll turn it over to Jose. Thank you, Clay. NOV's consolidated revenue for the first quarter of 2022 was $1.55 billion, a 2% sequential increase compared to the fourth quarter of 2021, and a 24% increase compared to the first quarter of 2021. Rapidly improving market fundamentals, growing global drilling activity, and actions taken to mitigate operational disruptions more than offset seasonal declines and continued extraordinary supply chain challenges. Adjusted EBITDA totaled $103 million or 6.7% of sales, a 220 basis point improvement in EBITDA margin compared to the fourth quarter, and a 670 basis point improvement compared to the first quarter of 2021, representing 34% EBITDA flow-through. Our GAAP results for the first quarter of 2022 included $45 million of other items, which were primarily due to the partial impairment of assets and other charges associated with our operations in Russia, Belarus, and Ukraine. Working capital increased $163 million, primarily due to a disproportionate number of shipments that occurred late in the quarter and intentional inventory builds to mitigate operational disruptions. Working capital was also affected by the normal increase in Q1 tax, employee benefit, and other payments, which further contributed to a $103 million use of cash from operations. Capital expenditures totaled $46 million for the quarter. While we've become more adept at navigating through the unprecedented number of ever-changing supply chain challenges, all of our businesses remain constrained by raw material shortages, with significantly protracted and growing lead times for subassemblies, castings, forgings, electronics, and motors. As a result, our throughput is constrained and we are not fully keeping up with inflecting demand. During the second quarter, we plan to build additional inventory buffers to position the organization to meaningfully improve throughput and operational results in the second half of the year. Moving on to segment results. Our Wellbore Technologies segment generated $608 million in revenue during the first quarter, an increase of $32 million or 6% compared to the fourth quarter and 47% compared to the first quarter of 2021. Growing global activity led by North America and the Middle East drove solid revenue growth across the segment's portfolio of businesses, despite headwinds from supply chain disruptions. Pricing gains and an improved product mix offset inflationary pressures to drive incremental margins of 41%, resulting in a $13 million sequential improvement in EBITDA to $101 million or 16.6% of sales. Compared to the first quarter of 2021, EBITDA improved $67 million, representing 34% EBITDA flow-through. Our ReedHycalog drill bit business posted revenue growth in the upper single digits, driven by strong performance in the U.S. and Middle East. A less favorable mix limited sequential EBITDA flow-through. However, the business unit realized a mid-40% incremental margin relative to the first quarter of 2021. Despite intense inflationary pressures on several key material inputs, the business has secured net pricing gains in most markets, and its leading-edge bit technologies position the business to continue its strong performance in the second half of the year. Our downhole business reported a low single-digit% improvement in revenue as solid growth in North America was offset by large Q4 shipments into international markets that did not repeat. This business unit has been disproportionately impacted by supply chain challenges, with difficulties accessing elastomers and special grades of steel used in our high-spec products, resulting in growing backlogs for our tools. In our primary North American manufacturing facility, backlog for our power sections increased 38% in Q1 due to stators awaiting relines. Despite and in part due to these difficulties, the business has been able to push pricing to partially offset the supply constraints and is executing on plans to significantly increase throughput during the second half of 2022. Our wellsite services business posted mid-teen sequential revenue growth with strong incremental margins. The business realized a solid full quarter contribution from its recent managed pressure drilling acquisition and strong contributions from the unit's core solids control operations. As activity increases and more rigs are reactivated, this business is particularly well-positioned, as we expect drilling contractors will look to differentiate their rigs with the latest generation of solids control and MPD equipment. Our M/D Totco business posted low single-digit sequential revenue growth with negative incremental margins due to the seasonal falloff in capital equipment sales into international markets and a less favorable sales mix. Despite the soft quarter, the business unit achieved 41% revenue growth with incremental margins in the 70% range in comparison to the first quarter of 2021 and had several recent commercial successes, which should drive wider adoption of the unit's newer technology offerings. Working in tandem with our rig business, the unit initiated a trial project with a key NOC in the Middle East utilizing our KAIZEN intelligent drilling optimizer running on our NOVOS platform. The project demonstrated notable drilling improvements, reducing average days to drill by 35% in comparison to offset wells. Additionally, M/D Totco's eVolve broadband wired drill pipe solution was commended by a key offshore customer for helping avoid a well control event. When the operator encountered an unexpected change in downhole conditions and a subsequent loss of well circulation, M/D Totco's wired drill pipe and distributed long string measurements continued to provide real-time annular pressure readings, which would not have been possible with mud pulse telemetry. This allowed the operator to effectively manage the situation and backfill the annulus. The operator estimated that the solution helped avoid a loss in hole incident, if not a full blowout. We expect adoption of M/D Totco's technologies to accelerate among leading operators as we continue to demonstrate meaningful improvements in drilling efficiencies, well productivity, and safety. Our Tuboscope business delivered a sequential revenue increase in the mid-single digits, driven primarily by improving demand in our U.S. inspection and Eastern Hemisphere coating businesses. Despite continued inflationary pressures on raw materials and labor, incremental flow-through for the business materially improved as demand is now driving opportunities to ratchet pricing at a rate that should outpace the combined effect on inflationary costs and operational disruptions. Our Grant Prideco drill pipe business posted mid-single-digit revenue growth with outsized incremental margins as the business realized a 15% increase in the mix of large-diameter premium pipe sales, which more than offset a dip in volume. While we expect supply chain disruptions, inflationary costs, and a slight deterioration in sales mix to result in softer Q2 results, new order outlook and pricing are growing increasingly favorable with tracked pipe inventories at near-record lows. For our Wellbore Technologies segment, we expect the continued improvements in global oilfield activity to drive revenue growth despite ongoing supply chain challenges, resulting in a sequential revenue improvement of 1%-5% during the second quarter. While we expect pricing for many of Wellbore's businesses will gain momentum, inflationary pressures will limit incremental flow-through to the mid to upper teens. We believe the segment is on track to achieve EBITDA margins in the high teens by year-end. Our Completion and Production Solutions segment generated revenues of $530 million in the first quarter of 2022, a decrease of 3% from the fourth quarter of 2021, but an increase of 21% compared to the first quarter of 2021. The sequential decline in revenue was driven by continued supply chain challenges along with typical seasonal declines. Despite the sequential decrease in revenue, adjusted EBITDA increased $8 million due to better execution against ongoing supply chain disruptions, improved product mix, and a better absorption in our manufacturing plants. While orders declined sequentially, book-to-bill was 110%, the fifth straight quarter in which the segment has achieved a book-to-bill greater than one. Quarter-ending backlog increased 6% sequentially to $1.36 billion, which is up 68% from the first quarter of 2021 and reached its highest level in more than five years. Q1 bookings were solid, but a number of our offshore customers took a step back and deferred new orders while they work with suppliers to get their arms around the unprecedented disruptions, delays, and rising costs in shipyards around the world. Despite this temporary pause, the outlook remains robust as improved commodity prices have significantly enhanced project economics despite rising costs. Our Process and Flow Technologies unit posted mid-double-digit sequential revenue growth in the first quarter as progress improved on several projects that experienced COVID-related disruptions over the last few quarters. While profitability for this business improved, margins remain at unacceptable levels due to cost overruns caused by shutdowns and quarantine-driven delays at shipyards and engineering cost overruns resulting from the inability to efficiently collaborate on complex projects while in remote work settings. We expect the magnitude of disruptions to decline, but the effects will continue to pressure results through the second half of the year. Our subsea flexible pipe business recorded a sequential revenue decline in the low single digits, but was able to achieve a modest improvement in profitability through a higher margin sales mix and through herculean efforts to control costs throughout the quarter to make up for a 3-week shutdown in one of our two manufacturing plants caused by a lack of raw materials. While the primary issue has been resolved, we expect profitability to remain challenged for this unit for at least the next quarter or two. Our intervention and stimulation equipment business experienced a low double-digit drop in sequential revenue, driven by strong Q4 coiled tubing equipment sales and a late 2021 push to sell lower margin prior generation capital equipment that did not repeat in Q1. Profitability improved due to a better product mix, higher pricing and incremental cost savings achieved during the first quarter, which more than offset continued inflation and supply chain challenges. Bookings increased 44% sequentially and included strong orders for a Hydra Rig 61-20 large diameter coiled tubing injector that provides 120,000 pounds of continuous lifting capacity and 60,000 pounds of continuous snubbing capacity. While we're not yet seeing demand for new units in North America, customers are realizing much improved pricing and are now upgrading existing units with better technology. This means aftermarket activity continues to drive our ISE business. However, during Q1, we saw a pickup in demand for wireline equipment in international markets and cementing equipment in the U.S., as we are also seeing U.S. pressure pumpers purchase additional pump units to supplement current fleets as horsepower demand per spread continues to increase. With our service company customers beginning to realize net pricing for the first time in several years and high-spec equipment nearing full utilization, we expect to see increasing sales of capital equipment moving forward. Our fiberglass systems business posted a sequential revenue decline in the upper single digits due to seasonality in our fuel handling systems operation and continued supply chain issues, which has made operations for this business particularly noisy. Many of our key inputs, such as glass, resin, and epoxy, were primarily sourced from Asia. With the dramatic increase in shipping costs and the inability to predict delivery times, the business has worked to diversify and reallocate its supply chain to better insulate it from disruptions. Despite the challenges faced by this business and the sequential revenue decline, the team was able to improve profitability in Q1 through a focus on cost control and pushing price to make up for increased costs associated with raw materials and operational disruptions. After a difficult 2021, the business is now seeing its sales pipeline grow at a rapid pace, particularly in the Middle East, portending improved results for the business in the second half of the year. While supply chain challenges and inflationary pressures will persist through the second quarter, execution from our completion and production businesses should continue to improve. As a result, we expect Completion & Production Solutions segment to achieve a 10%-15% increase in revenues with incremental EBITDA margins in the 15%-20% range. We continue to believe the segment can achieve mid to upper single digit EBITDA margins by year-end. Our Rig Technologies segment generated revenues of $441 million in the first quarter, an increase of $10 million or 2% sequentially. The modest top line growth was a result of rapidly improving market fundamentals, which are driving a growing backlog in both capital equipment and aftermarket offerings, mostly offset by seasonal declines and supply chain challenges that are restraining our ability to ramp production in lockstep with inflecting demand in our aftermarket business. Adjusted EBITDA improved $15 million to $36 million, or 8.2% of sales, due to a more favorable sales mix, improved pricing and cost savings initiatives. New orders totaled $236 million, representing a book-to-bill of 124%. We also posted an additional $80 million positive adjustment to our backlog, primarily related to an annual inflationary price index adjustment associated with our Saudi new build rig program. As a result, total backlog for the segment at quarter end was $2.89 billion, the highest level the segment achieved since Q1 of 2020. Demand for wind power installation vessel equipment remains robust, and we booked a large equipment package for a new wind power installation vessel during the first quarter. The award includes a jacking system, heavy lift crane, and a special feeder barge handling system, which is designed to provide a cost-effective Jones Act compliant solution that can improve installation process efficiencies by up to 30% compared to conventional vessels. The offshore wind power installation equipment market remains a compelling near-term opportunity, and we see the potential for 5-6 additional vessels reaching FID over the next 12-18 months. We're equally excited about NOV's mid to longer term opportunities within the wind power space. We've previously discussed our taller tower thesis, which continues to be the primary driver for improving economics in the wind power space and continues to drive our R&D efforts and the proprietary solutions we are developing for the market. We previously described a patented technology in which we've invested spiral weld tapered wind tower sections via an automated process, allowing for infield manufacturing, thereby eliminating the many logistical limitations of transporting the larger diameter sections necessary for tall tower developments. We are pleased to announce that production of the first commercial tower sections is now underway at our Pampa, Texas facility. While this system will address the logistical challenges and costs associated with delivering taller wind turbine towers to location, installing towers and nacelles with higher hub heights presents other challenges and opportunities. We're in the process of finalizing the design of a fit-for-purpose onshore mobile wind tower erection system, leveraging our core design and manufacturing competencies for large industrial capital equipment and experience developing complex control systems. This patent-pending system should significantly improve the safety, reliability, and efficiency of tall tower installations. Longer term, we're seeing the emerging floating offshore wind market as a compelling opportunity for NOV. Floating wind turbines will be key to unlocking the massive renewable energy potential in many markets around the world that don't have access to large areas of shallow coastal waters. Beyond our existing product portfolio, which includes cranes, winches, mooring systems, cable lay systems, ballasting systems, and chain connectors and tensioners, we're leveraging our deep expertise in marine and offshore engineering design and manufacturing to actively develop new products and technologies to support this nascent opportunity. Our patent-pending Tri-Floater semi-submersible floating system has a cost advantage shallow draft design that reduces steel requirements, capital expenditures, and overall project execution risk. We're also designing several proprietary lifting and handling tools to streamline the installation and commissioning of offshore wind turbine components. To date, we've completed several pre-FEED and FEED studies related to potential deepwater wind development projects, and we were recently awarded a pre-FEED study for a project in South Korea. We're also working with partners on several other potential projects around the world, including opportunities within the prospective 25-gigawatt ScotWind development area, where 17 seabed blocks covering 2,700 square miles were recently auctioned. Of the 17 blocks awarded, 11 will utilize floating wind systems, and NOV has been actively engaged in discussions with the winners of six of the 11 licensees. While there is no guarantee that NOV will be selected to equip these developments, we're well-positioned for this large long-term opportunity, which could result in pre-FEED activities taking place over the next two years, full FEED studies during 2024 and 2025, and construction beginning in 2026 with first power by 2030. We're enthusiastic about NOV's long-term prospects within the wind space, but remain extremely focused on our current wind power construction vessel opportunities and on the growing demand from our conventional rig equipment business. While orders for rig capital equipment in Q1 2022 were up 83% over Q1 2021, they remain light by historical measures. However, we're seeing accelerating improvement in underlying fundamentals. In the U.S. land market, leading-edge day rates for top-tier rigs are up to $30,000, up from the low 20,000s just a few quarters ago. The active rig count continues to march higher. We expect to see similar day rate dynamics for top-end rigs in international markets with improving activity. Leading-edge offshore day rates have climbed into the $300,000-$400,000 range, levels that are encouraging reactivation and reinvestment activities to accelerate and generating orders for both our aftermarket and capital equipment businesses. During Q1, we were awarded multiple contracts to help customers ready equipment for upcoming drilling campaigns, including an agreement with an international drilling contractor to reactivate 3 jack-up rigs and recertify an additional 8. We've seen a dramatic change in the sense of urgency among our customers. Last quarter, we described a rise in inquiries for top drives, high torque handling equipment, and pressure control gear, which are now converting into orders. During most of 2021, customers wouldn't have had any qualms incurring downtime to recertify pressure control gear. We're now seeing customers buy spare sets of blowout preventers to eliminate downtime during recertifications, avoiding the need to miss out on much improved day rates. While we welcome this newfound urgency and how it is creating opportunities to strip away the last vestiges of price discounts we offered during the depths of the downturn, major supply chain bottlenecks have frustrated and will continue to frustrate our efforts to ramp our output in step with surging aftermarket demand for at least another quarter. Supply chain constraints are impacting all our businesses, but are most acute within our rig aftermarket operation. While aftermarket revenues improved roughly 5% sequentially and growing demand from recertification, reactivation, and upgrade projects in North America and Europe allowed us to avoid the typical seasonal declines in service and repair work, revenues from spare parts sales declined, but not due to a lack of demand. In fact, spare part bookings increased 16%, achieving its highest level since Q1 of 2020, and was 67% higher than the low we saw in Q4 of 2020. Unfortunately, supply chain constraints led to a decline in revenue from spare parts sales and resulted in our backlog increasing 31% over Q4. We expect throughput to remain constrained through at least the second quarter as supply chain remains challenged and lead times continue to stretch. The supply chain bottlenecks are numerous and include difficulties procuring all sorts of raw materials, castings, forgings, electronic circuits, electric motors, gearboxes, and even large bearings. While most of the difficulties are due to lead times from third-party providers blowing out, we also made some of our own missteps related to underestimating how rapidly demand would begin to inflect. Over the past 18 months, we've been working to consolidate the operations of our large manufacturing facility in Orange, California, where we produce the bulk of our top drives into other plants in Houston and Mexicali. While this was a high degree of difficulty endeavor, the consolidation will generate meaningful cost savings. Prior to the moves, we built buffers of finished goods that we expected to carry us through the consolidation. The moves in associated manufacturing startups took longer than anticipated and occurred while demand was beginning to inflect. While we're now ramping production, the challenges we're facing with access to raw materials, castings, and forgings, along with our own manufacturing bottlenecks, will constrain our ability to keep up with demand through the second quarter. As a result, we expect operational headwinds will keep financial results for our Rig Technologies segment flat with those of the first quarter. However, we're growing increasingly confident in a much stronger second half of 2022 and in our belief that our Rig Technologies segment can achieve EBITDA margins of 10% by year-end. With that, we'll now open the call up to questions. If you'd like to ask a question at this time, please press the star then the number one key on your touchtone telephone. To withdraw your question, press the pound key. Our first question comes from Ian Macpherson with Piper Sandler. Thank you. Good morning, Clay, and Jose. Good morning, Ian. I appreciate the opening remarks. That was a really spot on overview of our recent history, and I'm sure that you'll be treated to drinks at the bar this afternoon, after that. Well, Ian, that was my goal. Well, exactly. There's always so much on the platter with NOV, and this might be a question that's too hard to pin down, but everything is heating up and congested right now. Are there two or three categories of products or within your main segments that are maybe the biggest catalyst for improvement with your throughput overall as we get into the second half and some of the supply chain gets unstuck? Is it the offshore, the big chunky offshore rig reactivation projects that move the needle the most? More on the offshore wind vessels, I think you said maybe five or six more that look like the one that you booked in Q1? Or is it the shorter cycle stuff that's accumulating and still has more of a congested backlog right now or otherwise? I'll let Jose offer his opinion. I'll just off the cuff, I would say, I think the shorter cycle, you know, catching up, improving the situation around our very, very constrained supply chain challenges, meeting sort of the near-term demand of supporting rigs and frac fleets and stimulation equipment going back to work both land and offshore. You know, I think that's kind of the biggest near-term needle mover for NOV. As Jose mentioned in the guidance, you know, we're facing some constraints in Rig around catching up on our spare parts backlog and working through that. But the other two segments as well are battling through. Longer term, yeah, I think these larger projects will contribute, and we're gonna continue to see good demand for renewables and offshore wind revenue opportunities for NOV. You know, what I like about where we are today is, and my opening remarks kind of reflected this, I feel like we're sort of at an energy crossroads, and it's gonna take all forms of energy. I think we've improved the optionality embedded in the portfolio of what we bring to not just traditional oil and gas and now LNG, but also to the renewable space, as well. Yeah. Ian, I think I'd add that. Yeah, I absolutely agree with what Clay said. You know, in the prepared remarks, we attempted to highlight a couple of the areas that are more constrained from a near-term standpoint in our Downhole Tools business and our Rig aftermarket operations. We've got some real constraints there, but really we've got those same kind of constraints all across the organization. We have constricted throughput due to the supply chain challenges that we've been having across the organization. Yeah, I think one of the things that Clay also touched on in his prepared remarks is that basically, you know, the need is for oil from all sources around the world, and we're starting to see that in the conversations with our customers. It's hard to single out any one specific business that over the mid to longer term is gonna do particularly better, because right now it feels like demand is on the cusp of inflecting all across the board. Clearly Wellbore has had a really nice recovery to date, but that recovery has been disproportionately weighted towards the North American marketplace. International market's starting to come on. Still see a lot of running room in terms of Wellbore's ability to continue to generate really good growth at good incrementals going forward. The other two segments being much more capital oriented, are really just starting to get up and going, and we've got to really resolve some of the supply chain constraints that we think will get much better or we'll be able to manage much better as we get into the second half. Okay, along that same vein, Jose, I think one thing that everyone in OFS and equipment has had in common this quarter has been more working capital intensity in the beginning of the year. You know, a symptom of better growth for the year. I don't know. I'm sorry if I missed this in your comments. Does that impact your prior view on getting to positive free cash flow for the full year? Does it move it out to next year, or do you see the swings coming back your way to positive free cash for the full year? Yeah. It's a good question, Ian, and it's really to be determined to some extent, and I'll explain what I mean by that. Really, you know, the use of cash in Q1 really shouldn't have been a surprise. You know, typically, that's what happens during Q1 due to you know, seasonality associated with employee benefit costs, tax payments, other annual type payments that take place early in the year. Additionally, as I mentioned during prepared comments, we had quite a large amount of our sales and products shipped late in the quarter, which resulted in a slightly bigger than anticipated build in AR, but also began taking much more proactive measures to build buffers within our inventory base to attempt to mitigate those supply chain disruptions. As we look forward, you know, we're not focused. Certainly, we've always been very focused on free cash flow generation throughout the cycle, right? But there are times in the cycle when things are going really well, meaning revenue is growing at a rapid pace to where that becomes a little bit more challenged. Through a combination of our view of, you know, a much higher exit rate to 2022 and the need to continue building buffers in our supply chain through the course of the year, we're not really extremely focused on making sure that we're free cash flow positive for the full year. What ultimately happens there will be dependent on the trajectory of the business, and we're anticipating there to be a pretty steep trajectory going into 2023. I would add, too, I think longer term, the organization's done a really good job of developing muscles around working capital intensity. If you look at our, you know, this quarter, I think we were 27% of annualized revenue, working capital intensity. At year-end, we're 25%. Those are materially lower than they were a year or two ago. We've gotten a lot better at this. As Jose said, in response to sort of making our supply chain a little more bulletproof, in response to vendors, for instance, having increasing their minimum order quantities, things like that's pushing us up a little bit. I think longer term, that better management of working capital is gonna translate to higher cash flow in the future. Noted. Thank you both very much. Appreciate it. Thank you. Thanks again. Our next question comes from Scott Gruber with Citigroup. Yes, good morning. Hi, Scott. Morning, Scott. Coming back to the outlook for Wellbore beyond the second quarter, if we do start to see some of these supply chain issues affecting that segment begin to fade, is there another period of growth in Wellbore in the U.S. that would be in excess of the rig count? Or are we at the point of the cycle where those begin to converge? Thinking on the international side of the business, obviously early innings, big service companies are discussing 15% growth in the second half. Just wanted to see if you guys would expect something similar for Wellbore on the international side. Yeah. I think a couple things that are helping Wellbore grow beyond sort of the rate of the rig count. Number one, I think we need to continue to get sort of real pricing increase across what we provide to the space. Number two, a lot of the technologies we've invested in are coming into the North American market and other markets as well, particularly around things like drill bit cutters that are demonstrating much better efficiency. Number three, drilling contractors are moving towards larger drill pipes. So there's been a big push by operators to utilize 5.5-inch drill pipe, which is a little bit bigger than more conventional 5-inch drill pipe. The reason that the operators are pushing for that are better hydraulics. We kinda are starting to see this need to swap out drill strings supporting the industry's drilling efforts across North America. You can add to that a number of sort of downhole tools, motors and things that again we've invested in technology that demonstrates better productivity. I think, you know, it's a pretty good tailwind to outperform rig count growth in Wellbore Technologies. Also too, probably wanna mention our digital offerings in the space. Our M/D Totco group within Wellbore Technologies is getting really good traction on a number of things that they're doing with their edge computing solutions, as well as their wired drill pipe drilling optimization offerings. Scott, maybe the other thing I'd add is, look, if you sort of you know, we don't necessarily expect everything to play out the way that it has in the past, but sort of looking at sort of recent performance of the Wellbore segment, you know, you go back to the prior dip, you know, in 2016, which was sort of the prior low mark for the business. It was about $511 million in revenue for the segment. We're roughly 19% above that level right now. Then you go back to sort of the 2018, 2019 timeframe for that segment, and, you know, we were pushing over $800 million a quarter in revenue for that segment. As you recall back then, we saw a nice recovery in the North American marketplace, but really never fired on all eight cylinders with a strong international market. Here, as we're sort of looking at, you know, a prolonged multi-year upcycle, I think there's still a tremendous amount of upside over the long term for the Wellbore Technologies segment. That's a good lead into my follow-up question, which is on the international side. You know, there just still seems to be an unduly large technology gap, you know, between onshore drilling in the US and the rest of the world. As we think about, you know, the retooling cycle here, is this just gonna be a typical retooling cycle internationally, or do you sense a real appetite to meaningfully enhance the technology deployed? You know, thinking about material upgrades to rigs, potentially new build rigs, and then obviously the digital application side of things. You know, are you starting to sense real appetite to meaningfully step up the technology deployed internationally? That is a great question. I think a lot of operators around the Arabian Gulf are watching sort of what's happened in North America with respect to big gains in drilling efficiency and leaps and bounds that the industry here has been able to accomplish and then looking at their own rig fleets and capabilities. You know, it's different rocks, different set of challenges, but recognizing, you know, there's a lot of improvement that can be brought to bear in that region, and it really needs to be brought because a lot of those countries around the Middle East are now looking at the need to produce more natural gas. They're looking at unconventional technologies to make that happen, and that really rests squarely on much better drilling efficiencies. That was you know, that all kind of went into the to the calculus, I think, around our joint venture with Aramco in the Kingdom to build out rig manufacturing capabilities. These are gonna be much higher capability rigs that we're producing there. We delivered the first one in January. We'll soon have the second one ready to go. That's gonna bring new technology. I would add, and this is, I think, pretty important and it was in our release as well as Jose's prepared remarks, we've had recent pilot projects around the Middle East region, where now the national oil companies are trying our new digital products and our machine learning, artificial intelligence capabilities to optimize drilling. One of the NOCs is getting ready to spud its third pilot with wired drill pipe. There's a lot of interest in the possibilities of new technology, a lot of interest in what NOV can bring to their drilling efforts there to make them not only more efficient but safer, more predictable. I think we're really set now for a meaningful sort of retooling of capabilities across the Middle East region. Appreciate the color. Thank you. You bet. Thanks, Scott. Thanks, Scott. Our next question comes from Arun Jayaram with JP Morgan. Yeah, good morning. Clay, I wanted to get your thoughts on how the long cycle part of your business could play out from here. We see a couple of divergent trends. One, you know, obviously high commodity prices and energy security concerns, particularly post Russia-Ukraine. On the other hand, your traditional OFS clients appear to be much more measured on spending growth capital, or adding incremental capacity, with most of their CapEx now focused, call it, on refurbishments and reactivation. Wanted to see if you could offer some thoughts there. Yeah, it's a really good question, Arun. I would say all upcycles sort of start this way. People come out of the bottoms having just reduced a lot of costs and had to shrink their workforce and being very stingy with their expenditures are careful about reinvesting in the business. You know, as I mentioned, I think we're facing some pretty significant structural challenges getting production really back to growth on a global basis. I think what we're gonna run into is that they're gonna run out of rigs to reactivate, out of frack fleets to put back in the field. The ones that are left have been cannibalized, and so that just. It takes capital. I think as they gain pricing power, which this quarter's been really interesting to kind of hear their reports of how their first quarter looked, it feels like to us they're getting a lot more pricing power across their businesses. That sort of paves the way for reinvestment in their fleets and to kind of build out the infrastructure required, which, look, at the end of the day, you have to put heavy assets back in the field to drill wells and bring production on. I think this will all follow as we get kind of deeper into this and the supply chain structural challenges become more evident. The other thing that really has to happen, and this is now I'm kind of shifting to the offshore, the you know, capital availability to the offshore. Many of the public drillers have just come out of bankruptcy. I, as I said, I think it's the production's gonna be required from really all sources as we move for the next few years. We see rising day rates then becoming more supportive of higher cash flows. That'll reduce the cost of capital to those drillers. We'll kind of get back to growth, which is something I think the world's gonna sorely need. Great. Just my follow-up, you know, Jose, just looking at kind of the numbers, you know, NOV essentially was able to deliver it in 1Q what the Street was modeling in terms of 2Q in terms of EBITDA. I'm getting just some questions around, you provided some color on, you know, revenue growth and some broad margin comments. We kind of stuck in your Wellbore CAPS and Rig Technologies guidance in our model, and we were getting, call it, EBITDA in the low 120s. I was wondering if you could maybe give us a range of views on if our math is in the ballpark around 2Q. Yeah. So I think we're pretty clear in terms of the typical guidance that we give by segment for each of the three segments in our prepared remarks. As usual, we'll be posting a copy of the prepared remarks immediately following the call, so you can get additional clarity on that. You know, in terms of where you're coming out, I think if you take the midpoint of the range that we provided, you're not far off of that guidance. Great. Thanks a lot. Thanks, Arun. Our next question comes from Marc Bianchi with Cowen. Hey, thanks. I wanted to go back to the kind of order outlook. You guys had some prepared remarks about, and it was just discussed in the prior conversation, about customers having a lot of pricing power now, you know, rig rates getting back to $30,000 or getting up to $30,000 a day. That would seem like a level where they should be pursuing new builds. If you go back to all the public company calls, they were all saying, you know, "We're not gonna build. We're gonna be capital discipline and so forth, like our customers." I'm curious, is your view more based on what they should be doing, or are you getting feedback and doing RFPs for potential new builds? Maybe it's from the privates. I'm just curious if you could help square that for us. Well, first, if you look at the absolute rig count, let's talk about North America first. The absolute rig count still is not to where it was pre-pandemic, right? There's still a lot of iron that's underutilized out there. As Jos mentioned, we are supporting their efforts to reactivate rigs, put them in the field. As well as if you compare today's market versus the pre-pandemic market, their costs are higher and so forth, so they need a higher day rate to attract new builds. Our outlook for new build rigs in land rigs in North America, you know, yeah, that could come. It is, you know, at least several quarters out, if not longer. If you pivot to look at international markets, particularly Middle East, for the reasons I just mentioned, I think that's where we really start to see a lot more interest in just outright new builds. That's kind of how I would see the next, you know, call it 18 months playing out, Marc. Mm-hmm. Okay, that makes sense, Clay. I guess in that vein, you know, everybody's kind of curious when we're gonna see the real inflection in orders. I guess second quarter of last year, things started to get back on track, but we've sort of been stuck in this range for several quarters now. I would suspect that maybe inflation is making it difficult. There's a lot of rewriting of terms and things like that as you try to get orders booked. What does that look like over the next several quarters? Worth noting, I mean, we've had five quarters in a row of book-to-bill north of one. You know, orders have been going the right way, and our backlog has been building. My prior answer referred most obviously to land rig demand pivoting to CAPS. CAPS backlog, I think, has roughly doubled year-over-year. You know, our outlook is really, really good. Orders went down sequentially for CAPS, but book-to-bill at 110% was still north of one, right? We're still building backlog, and backlog was up a few percent sequentially for the Completion & Production Solutions. One of the near-term headwind, challenges we gotta work through for CAPS, it's more obviously more production related, and so these are large projects for the offshore that they're tendering and looking at booking. Some of the owners of those projects in the first quarter are getting revised cost estimates from our groups, right? As we look back on our recent experience fabricating projects in Asian shipyards and all the headaches we've been battling through with COVID and supply chain disruptions and so forth, along with other vendors in that ecosystem doing the same thing, along with the fact that a lot of the shipyards are seeing, you know, as wind demand has picked up, as LNG demand has picked up, they're looking at a little higher costs on these projects. In the first quarter, I know a few of them are drawing a deep breath and just sort of, you know, revisiting their conviction around higher price decks, offsetting the higher costs. I think the economics are still good. I think orders are gonna flow. But here in the near term, I think that's been a little bit of a break on recent orders. But nonetheless, you know, let's don't overcomplicate this. Oil is trading at a really high price. There's been a lot of re-engineering, a lot around a lot of these big projects around the globe. They are needed by the globe. I think that'll become more evident as the year and next year unfolds. I think these projects are going forward, and that's gonna translate to higher orders for NOV. Great. Thanks so much, Clay. I'll turn it back. Thank you. That concludes today's question and answer session. I'd like to turn the call back to Clay Williams for closing remarks. Great. Thank you. I appreciate everyone joining us this morning, and we look forward to discussing our second quarter results with you in late July. Have a good day. This concludes today's conference call. Thank you for participating. You may now disconnect.