Good day, everyone, and welcome to today's Helmerich & Payne Fiscal Fourth Quarter Earnings Call. At this time, all participants are in a listen-only mode. Later, you will have an opportunity to ask questions during the question-and-answer session. You may register to ask a question at any time by pressing the star and one on your touch-tone phone. Please note this call may be recorded and I will be standing by should you need any assistance. It is now my pleasure to turn today's program over to Dave Wilson, Vice President of Investor Relations. Thank you, Brittany, and welcome everyone to Helmerich & Payne's conference call and webcast for the fourth quarter and fiscal year ended 2021. With us today are John Lindsay, President and CEO, Mark Smith, Senior Vice President and CFO, and John Bell, Senior Vice President, International and Offshore Operations. John Lindsay and Mark will be sharing some comments with us, after which we'll open the call for questions. Before we begin our prepared remarks, I'll remind everyone that this call includes forward-looking statements as defined under the securities laws. Such statements are based upon current information and management's expectations as of this date and are not guarantees of future performance. Forward-looking statements involve certain risks, uncertainties, and assumptions that are difficult to predict. As such, our outcomes and results could differ materially. You can learn more about these risks in our annual report on Form 10-K, our quarterly reports on Form 10-Q, and our other SEC filings. You should not place any undue reliance on forward-looking statements, and we undertake no obligation to publicly update these forward-looking statements. We will also be making reference to certain non-GAAP financial measures, such as segment operating income and other operating statistics. You'll find the GAAP reconciliation comments and calculations in yesterday's press release. With that said, I'll turn the call over to John Lindsay. Thank you, Dave. Good morning, everyone, and thank you for joining us today. I'm excited to be in Abu Dhabi this week, having just participated in the ADIPEC conference, which has provided a unique occasion to meet face-to-face with colleagues, customers, and of course, our strong partner, ADNOC Drilling. Also joining Mark and me today in Abu Dhabi is John Bell, Senior Vice President, International and Offshore Operations, and he'll be available for international and ADNOC-specific questions. Before getting into our traditional discussion topics, I wanted to first mention that ADIPEC, which is a global energy conference in Abu Dhabi, and this week there was over 150,000 attendees, 33 energy ministers and representatives from over 50 energy companies. I've been impressed with the focus on ESG and especially discussions of the impacts on energy security for the globe. In addition to industry leaders sharing their focus on sustainability and ESG, there were also leaders of countries from around the globe that were present to give their perspectives on the energy transition and the importance of ongoing investments to ensure a smooth transition. Dr. Sultan Al Jaber, the ADNOC Group CEO and UAE Minister of Industry and Advanced Technology, gave a very compelling speech at ADIPEC's opening ceremony. He started with a reminder that energy transitions take multiple decades, and I quote, "Rewiring the energy system is a multi-trillion-dollar business opportunity that is good for humanity and good for economic growth." He also had a call to action stating, "What the world really needs is to hold back emissions, not progress. Let us together drive that progress. Let us always keep in mind, our industry must play a pivotal role in the energy transition. We have the knowledge, the skills, and the people to make a difference in our world." Now, that statement really resonates with me. Working with our customers to reduce emissions and our collective environmental footprint is a major area of focus for us here at H&P. The strategic alliance we signed with ADNOC is a great opportunity to deliver rig technology through the sale of eight high-spec H&P FlexRigs, as well as to make a significant $100 million investment in their initial public offering. ADNOC has a 2030 oil production target of 5 MMbpd and a goal to achieve natural gas independence. We believe H&P can make significant contributions towards helping ADNOC achieve those goals through this new partnership, while also providing additional opportunities for us to expand in this pivotal and growing energy region. We're delighted with the reception H&P has received this week, and we wanna thank the ADNOC team for their hospitality. Looking at the rest of our international activity, historically, we've experienced a lag compared to the U.S., so we are expecting activity to improve in these markets in the coming quarters. A recent example is a couple of new agreements with YPF, as we will put four rigs back to work under term contracts in Argentina during fiscal 2022. We continue to pursue other international opportunities and look forward to improving activity. Shifting to North America Solutions, it is hard to believe that a year ago, H&P had only 80 active rigs running. Today we have 141 active FlexRigs. The response of our people and their leadership through the pandemic has been nothing short of amazing. Particularly impressive is their service attitude in responding to customers as rig demand has been recovering. Our folks are resilient and deliver on safety, efficiency, and reliability for our customers each and every day. We expected that the rig activity increases would be more measured during our fourth fiscal quarter as we realized more rapid rig churn among customers who are sticking to their disciplined spending plans. Given that, we were pleased with the 5% incremental rig count increase experienced during the quarter, and are even more optimistic as we look ahead to the fourth calendar quarter, where we expect to see our rig count increase sequentially and at a higher pace as E&Ps reset their annual capital budgets. We believe our customers will remain disciplined, and similar to 2021, the budgets for 2022 will be adhered to, but the new budgets will be reset at higher levels based on a higher commodity price environment, meaning more active rigs in 2022. As evidenced by our rig count growth to date, we expect the rig count will have a significant increase in calendar Q4 of 2021 and Q1 of 2022. As mentioned, our U.S. land rig count stands at 141 rigs today, up from 127 at September 30, our fiscal year-end. We expect to add roughly another 10-15 rigs by year-end of calendar 2021. To summarize North America Solutions, during calendar fourth quarter, we expect to add 25-30 rigs. To put that in perspective, this is approximately the same number of rigs we added in the preceding nine months. Further, we [reactivated] several more rigs during the first fiscal quarter that we expect to commence work in the first half of January. This activity increase is exciting as our customers are investing in their calendar 2022 budgets. It does, however, cause near-term margin compression due to the one-time expenses incurred for reactivation. Mark will discuss the details more in a moment, and I'll add that we are pleased with the future cash generation these rigs will have post-reactivation as we return to greater scale operations, driving both pricing higher and leveraging our fixed costs. Given the well-publicized challenges and what we hope is finally a post-pandemic environment, it's not surprising to see rig reactivation and field labor costs increasing. All of the super-spec rigs that are available to work today have been idle for well over a year, which equates to higher start-up costs. Competition for quality people is also escalating, and we will be increasing field labor wages accordingly. As a reminder, those cost increases are passed through to the customer. The tightening supply of readily available rigs, coupled with these cost increases, have already begun to move track pricing upward in the market. Based upon what we are experiencing today, we expect price increases will become even more pronounced in the coming months as rig demand picks up heading into 2022. Mark will talk about our strong balance sheet in his remarks, but I wanted to mention one of our goals was to generate free cash flow, and we are encouraged that we believe that is achievable in the back half of 2022 with the rig count and revenue expectations we have. These market conditions demonstrate further potential for H&P's new commercial models and digital technology solutions. Our digital technology solutions deliver value through improved efficiencies, reliability, lower cost, and better overall outcomes. Today, approximately 35% of our FlexRigs are on performance contracts, and several customers are experiencing the powerful synergies, a combination of performance contracts and digital technology can deliver. Adoption continues to improve and is driving economic returns higher, not only for our customers, but for ourselves as well. In closing, we are encouraged heading into 2022, and fully expect that the demand for H&P's drilling solutions will continue. E&P capital discipline, rising commodity prices, and a collective vision to play our crucial role in a smooth energy transition will strengthen the industry. There are still many challenges, but I'm confident that our people and solutions have the company well-positioned to deliver value for customers and shareholders in this improving environment. Now I'll turn the call over to Mark. Thanks, John. Today, I will review our fiscal fourth quarter and full- year 2021 operating results, provide guidance for the first quarter and full fiscal year 2022 as appropriate, and comment on our financial position. Let me start with highlights for the recently completed fourth quarter and fiscal year ended September 30, 2021. The company generated quarterly revenues of $344 million, versus $332 million in the previous quarter. The increase in revenue corresponds to a modest increase in our rig count during the quarter. Correspondingly, total direct operating costs incurred were $269 million for the fourth quarter versus $257 million for the previous quarter. During the fourth quarter, we closed on two transactions with ADNOC Drilling. First, H&P sold eight FlexRig land rigs, including two already in Abu Dhabi, and six from the United States for delivery during 2022. Consideration received for this sale was $86.5 million, and any gains above book values, together with required investments to prepare and deliver the rigs, will be recognized as each rig is delivered. Second, H&P made a $100 million investment in ADNOC Drilling in conjunction with its initial public offering in early October. General and administrative expenses totaled $52 million for the fourth quarter, higher than our previous guidance, due primarily to professional services fees associated with the ADNOC transactions and our ongoing cost management efforts, as well as increases to the short-term incentive bonus plan accrual to reflect full fiscal year operating results. On September 27, we issued $550 million in unsecured senior note bonds to refinance our $487 million outstanding bonds that were due in May 2025. Our new issuance came at a coupon of 2.9% in a 10-year tenor, maturing in September 2031. The additional debt of about $63 million funded the make-whole provision and accrued interest for the call of the existing bonds, as well as associated transaction costs. This made the transaction and subsequent debt extinguishment in October liquidity neutral. Also, note that the make-whole premium and accrued interest will be recognized in the first fiscal quarter 2022, concurrently with the October 27 redemption. Our Q4 effective tax rate was approximately 24%, in line with our previous guidance. To summarize fourth quarter's results, H&P incurred a loss of $0.74 per diluted share versus a loss of $0.52 in the previous quarter. Earnings per share were negatively impacted by a net $0.12 per share loss of select items, which are primarily made up of non-cash impairments for fair market value adjustments to equipment that is held for sale, as highlighted in our press release. Absent these select items, adjusted diluted loss per share was $0.62 in the fourth fiscal quarter, compared with an adjusted $0.57 loss during the third fiscal quarter. For fiscal 2021 as a whole, we incurred a loss of $3.04 per diluted share. Again, this was driven largely by the non-cash impairments to fair value for decommissioned rigs and equipment, the majority of which were previously impaired and are held for sale. Collectively, these select items constituted a loss of $0.44 per diluted share. Absent these items, fiscal 2021 adjusted losses were $2.60 per diluted share. Capital expenditures for fiscal 2021 totaled $82 million, below our previous guidance due to the timing of supply chain spending that crossed into fiscal 2022. Relative to our original guidance range of $85 million-$105 million, the variance was primarily driven by a delay in the start of planned IT infrastructure spending that we have previously discussed. Most of that planned IT spend will now be incurred in fiscal 2022. H&P generated $136 million in operating cash flow during fiscal 2021. Considering the pro forma impact of our recent debt refinancing, the collective cash and short-term investments balances decreased minimally by $7 million year- over- year, due in part to working capital improvements achieved during fiscal 2021, as well as asset sales. I will discuss in more detail later in my prepared remarks. Turning to our three segments, beginning with the North America Solutions segment. We averaged 124 contracted rigs during the fourth quarter, up from an average of 119 rigs in fiscal Q3. We exited the fourth fiscal quarter with 127 contracted rigs. Revenues were sequentially higher by $12 million due to the aforementioned activity increase. North America Solutions operating expenses increased $18 million sequentially in the fourth quarter, primarily due to the addition of six rigs as well as a higher material and supplies expense. Throughout fiscal 2021, we prudently managed our expenses and inventory levels using previously- expensed consumable inventory harvested during stacking activities in calendar 2020, rather than utilizing fully costed inventory or purchasing new inventory. As rig activity increased, our level of previously- expensed inventory, or what we have been referring to internally as quote-unquote penny stock, has been exhausted, resulting in the issuance of higher cost inventory and the purchasing of additional inventory to replenish stock levels. Replenishments go on the balance sheet. Through fiscal 2021, we did not experience inflation in our costs. However, we are anticipating inflationary pressures moving forward, which I will touch on in a moment. Additionally, as I will expand on later, we put six rigs to work in the first half of October, the first fiscal quarter of 2022, but the reactivation costs were primarily incurred in fiscal 2021. The one-time reactivation expenses associated with all of those rigs was $6.6 million in fiscal Q4. Now looking ahead to the first quarter of fiscal 2022 for North America Solutions, as expected, rig count growth was moderate during the fourth fiscal quarter. Publicly- traded customers continue to operate within their calendar year budget plans, which are currently being reset for calendar 2022, in an oil and gas commodity environment that is significantly more robust than this time last year. Accordingly, we expect to see sizable spending increases, especially with our public company customers, during the first fiscal quarter of 2022. As of today's call, we have 141 rigs contracted, and we expect to end our first fiscal quarter with between 152 and 157 working rigs, with current line of sight for a few additional rigs turning to the right in early January. In the North America Solutions segment, we expect gross margins to range between $75 million and $85 million, inclusive of the effect of about $15 million in reactivation costs. As I mentioned last quarter, there is a positive correlation between the length of time a rig has been idle and the cost required to reactivate it. Most of the rigs we are reactivating in the first quarter have been idle for 18+ months. Reactivation costs are mostly incurred in the quarter of startup, so the absence of such cost in future quarters is margin accretive. As John mentioned, we are expecting to achieve higher pricing in light of higher demand and tight ready-to-work super-spec supply. I will now pause to comment on inflationary considerations ahead for fiscal 2022. We have seen increases in commodity pricing, such as for steel. Products reflecting upward pricing due to this pressure include capital items such as drill pipe. Note that our upcoming capital expenditure guidance is inclusive of such pricing increases. For margin-related expenditures, I will touch on two items. First, maintenance and supplies pricing is increasing across some categories, such as oil-based products like lubricants and steel-based products like fluid ends. Second, as John discussed, we are increasing field labor rates to respond to market conditions and assist in talent retention and attraction. Further, our contracts are structured to pass through labor price increases over a 5% threshold. Therefore, significant labor increases are margin neutral due to contractual protections. Our margin guidance is inclusive of our expectations for inflation in the first fiscal quarter. As it relates to supply chain access to parts and materials to run our business, we are in constant communication with our suppliers and have placed advanced orders for certain higher-risk categories. Our proactive approach to inventory planning, coupled with our scale and healthy vendor partner relationships, provides reasonable assurance that supply chain issues as we see them today will not materially impact our business. We will continue to engage our suppliers and partners to stay ready to adjust as developments unfold. Subsequent to September 30, 2021, we sold two peripheral service lines which provided rig move trucking and casing running tool services to a portion of our North America segment customers. These business lines were largely margin- neutral to H&P, having collective revenues in the fourth quarter and full fiscal year of 2021 of $10 million and $34 million, respectively. To conclude comments on the North America Solutions, our current revenue backlog from our North America Solutions fleet is roughly $430 million. Regarding our International Solutions segment, international business activity increased by one rig in Argentina to six active rigs during the fourth fiscal quarter. As we look to the first fiscal quarter of 2022 for international, activity in Bahrain is holding steady with the 3 rigs working, and we expect to go from three to four rigs working in Argentina, as well as get the contracted Colombia rig turning to the right. Note that three of the YPF rigs John mentioned earlier will commence work in subsequent FY 2022 quarters in Argentina. Turning to our offshore Gulf of Mexico segment, we continue to have four of our seven offshore platform rigs contracted. Offshore generated a gross margin of $8 million during this quarter, which was within our guided range. As we look to the first quarter of fiscal 2022 for offshore, we expect that the segment will generate between $6 million-$8 million of operating gross margin. Now, let me look forward to the first fiscal quarter and full fiscal year 2022 for certain consolidated and corporate items. As we increase our rig count, capital expenditures for the full fiscal 2022 year are expected to range between $250 million-$270 million. This capital outlay is comprised of three buckets similar to fiscal 2021. First, maintenance CapEx to support our active rig fleet will be approximately 50% of the total FY 2022 CapEx. In fiscal 2019, we had bulk purchases in CapEx to scale up rotating componentry for then 200+ working super-spec FlexRig count. In addition, we harvested components from previously impaired and decommissioned rigs to conserve capital. As such, we were able to utilize resources on hand and preserve capital in 2021. Now we have reached the end of those inventories and we are needing to recommence a regular cadence of component equipment overhauls and drill pipe purchases. This, coupled with the sharp activity increase we are experiencing, is driving our fiscal 2022 maintenance CapEx back into our historical range of between $750,000 and $1 million per active rig per annum in the North America Solutions segment. Second, skidding to walking capability conversions will approximate 35% of the fiscal 2022 CapEx. Although our peers have walking rigs available in the market, select customers prefer certain rig design elements and commit to a conversion. For customers that need walking rigs, we will invest to convert certain rigs from skidding to walking pad capability in exchange for a term contract that will enable the new investment, which we currently estimate is $6.5 million-$7.5 million per conversion. Third, corporate capital investments will be about 15% of fiscal 2022 CapEx. Over half of this bucket is comprised of modernization for data center, data and analytics platforms, and enterprise IT systems, most of which has moved from fiscal 2021 to fiscal 2022 and will improve our infrastructure and cybersecurity posture. Portions of the balance of this corporate capital investment are for power solutions capital associated with ESG research and development efforts and for certain real estate matters. As part of the ADNOC sale transaction mentioned earlier, we will deliver the eight rigs to ADNOC throughout the year of 2022. The sale proceeds of $86.5 million were received in September 2021 and are included in accrued liabilities on our balance sheet. In addition to the capital expenditures just described above, we will spend approximately $25 million in cash to prepare and deliver the rigs to ADNOC. When we incur these expenses, they, together with the net book values, which among other assets, are classified in assets held for sale, will collectively represent the accounting basis in the rigs for the purpose of determining gains to be recognized in the upcoming quarters upon each delivery. Depreciation for fiscal 2022 is expected to be approximately $405 million. Our general and administrative expenses for the full 2022 year are expected to be approximately $170 million, which is roughly consistent with the year just completed. Fiscal 2022 SG&A will be partly front-loaded in the first fiscal quarter due to short-term incentive compensation payments for fiscal year 2021 results and the timing of certain professional services fees. Specifically, we expect $45 million-$85 million in Q1, with the remainder spread proportionally over the final three quarters. Our investment in research and development is largely focused on autonomous drilling, well bore quality, and ESG initiatives, and we anticipate these innovation efforts to yield further enhancements and solutions offerings on our technology roadmap. We anticipate R&D expenditures to be approximately $25 million in fiscal 2022. We're expecting an effective income tax rate range of 18%-24% for fiscal 2022. In addition to the U.S. statutory rate of 21%, incremental state and foreign income taxes also impact our provision. Based upon estimated fiscal year 2022 operating results and CapEx, we are forecasting another decrease to our deferred tax liability. Additionally, we are expecting cash tax in the range of $5 million-$20 million. Now looking at our financial position. Helmerich & Payne had cash and short-term investments of approximately $1.1 billion at September 30, 2021. When considering the aforementioned 2025 bond repayment and make-whole premium that occurred in October, the pro forma cash and short-term equivalents of September 30, 2021 were $570 million, sequentially compared to $558 million at June 30, 2021. Including availability under our revolving credit facility, but excluding the $546 million 2025 bond extinguishment amount, our liquidity was approximately $1.3 billion commensurate to the prior quarter. Our debt- to- capital at quarter end was temporarily at 26% given the debt overlap at the September 30 balance sheet date. Accounting for the repayment of the 2025 bonds, however, pro forma debt- to- capital adjusts down to 16%. Our working capital stewardship since the March 2020 downturn resulted in cash accretion. As we look forward towards the end of fiscal 2022, we do expect to consume a modest amount of cash given the one-time recommissioning expenses together with net working capital increase as our rig activity climbs. Fiscal Q1 will experience lower cash flow from operations in the following quarters due to the rig ramp-up and the seasonal cash expenditures for incentive compensation, property taxes, et cetera. We do expect to end the fiscal year with between $475 million-$525 million of cash on hand and $25 million-$75 million of net debt. In summary, we are expecting to generate free cash flow that, when combined with the modest uses of cash on hand early in the fiscal year, will cover our capital expenditure plan, debt service cost, and dividends in fiscal 2022. The growth in rig count early in the fiscal year provides a platform for cash generation in the second half of the year that, pointing forward, fully covers our cash uses, including our dividend, and sets the stage for further cash accretion. Our balance sheet strength, liquidity level, and term contract backlog provide H&P the flexibility to adapt to market conditions, take advantage of attractive opportunities, and maintain our long practice of returning capital to shareholders. That concludes our prepared comments for the fourth fiscal quarter. Let me now turn the call back over to Brittany for questions. At this time, if you would like to ask a question, please press the star and one on your touch-tone phone. You may remove yourself from the queue at any time by pressing the pound key. Once again, that is star and one if you would like to ask a question, and we will take our first question from Arun Jayaram with JPMorgan Chase. Yeah, good morning. I wanted to get a little bit more color around the fiscal year 2022 CapEx program. It looks like you're spending around $90 million or so on the walking system upgrades. You mentioned $6.5 million-$7.5 million type upgrades. Can you give us a sense, firstly, of the 95 idle rigs at H&P? You know, how many of those have walking systems on them? And for the next batch of, you know, reactivations that you expect to do, you know, how many more upgrades you anticipate? And secondly, can you comment on the amount of reimbursements over and above your daywork margins? What kind of reimbursements you're getting for those investments in the walking systems? On the investments, I think we're, Dave, correct me if I'm wrong. I think we've got one a month? Is that right on the walking rig? That's correct. Yeah. That is right. We're planning about one a month currently, John, based on line of sight with customers. That will adjust potentially up or down based on customer demand. Getting back, I think, to come back to the pricing and term we're getting, I'd just let John maybe start us off with a little bit of the commentary on why customers are asking us to convert. Yeah. I mean, it's interesting, Arun, because there's about 214 idle super-spec rigs in the U.S., and 124 of those are walking rigs. We've got significant demand, and all of our walking rigs are active, and we have significant demand for walking. It's clear that there's more demand than just for walking. There's obviously a demand for what H&P provides in terms of overall performance. That's a key— I think that's a key element. We are getting, you know. I think the last contract, we probably had an 18-month term contract, and I think- At $25,000 a day, actually. Yeah. Yeah. Specifically to your point, Arun, we're getting terms, we're shooting for two. The typical payback on these is three years, and commanding a premium price for doing so. Great. I think to start, I wanted to clarify something, though, Arun. I thought I heard you, and maybe I misheard. You said $190,000 — $190 million, pardon me, on the walking rig upgrades. No, I said $90 million. I just— [crosstalk] $90 million. Okay. Yeah, I thought it was, yeah, $ 84 million-$90 million, but I thought you said $190 million. I misheard. Yeah. Okay. Yeah, it was $90 million. Just my follow-up would be on the ADNOC rigs, Mark, $86.5 million of proceeds from that. Obviously, you also get the $100 million investment. Can you comment on the CapEx required in fiscal year 2022 to get those rigs in a condition to be sold? Well, as I mentioned, it's about $24 million, $25 million, I think, in the prepared remarks. It's a couple of things. There's some specific technical components that our partner wanted, one. Two, we're gonna be recertifying everything so that, for example, the BOP leaves with a five-year certification and the top drive leaves with seven years, et cetera. There's also the transit costs, so the shipping or mobilization costs to get those rigs across the water. What I have not commented on is the net book value by rig. Obviously, the eight have different values, and two are already in Abu Dhabi. The six in the U.S., two of the six were super-spec, as we've previously stated. Great. Thank you very much. Thank you. We will take our next question from Derek Podhaizer with Barclays. Your line is now open. Hey, good morning, guys. Wanted to talk more about the ADNOC deal. Obviously, the news just came out. We saw they just announced pretty significant tender just to support the growth of the 5 MMbpd. You talked about expanding into the region. Can you just maybe expand to us a little bit more about what you're talking about? Are these gonna be more H&P-owned rigs going in there? I think you talked about consultancy work. Just any more color you can give us on how you see yourself growing with ADNOC in this new partnership. Yeah. Derek, this is John. I'll start, and I'm gonna hand it over to John Bell to give additional color. I think in general, you know, the strategic partnership with ADNOC is very important. You know, our hope is that we can continue to expand internationally, both with ADNOC Drilling, as well as, you know, there are some areas that make sense that the H&P operation would be there. Go ahead, John. Yeah. John, as you said, we have. Right now we're focused on just getting the rigs ready and getting the people on board to start up the rigs, but also support the— We're in the process of fine-tuning a rig- enablement framework agreement that will give us the structure we need to provide ADNOC with the support they need in areas like maintenance, supply chain, operational efficiencies, and so forth. That's really what we're focused on. We have had discussions with them about different ways we might approach certain countries and customers in the region that and we're open to looking at that, but there's nothing that we've firmed up at this point. Does that help? Okay. Yeah, yeah. No. Appreciate the— Yeah. I think there's a real opportunity, though, on the partnership. I mean, I think this week has been a great example. We've had excellent meetings with ADNOC Drilling, and they're very excited about the future. You know, there are some obviously different service contracts and technology opportunities that we have to explore. Again, you said it, you saw the announcement, 5 million bbl and they have a goal of getting to natural gas independence. A lot of that work is unconventional and that really is a sweet spot, obviously, for H&P. You know, our hope is to be able to work closely with them, you know, to help them to achieve those goals. It's a really exciting opportunity. That's great. Switching over to the North America side, the contract coverage has stepped up pretty significantly quarter-over-quarter. Maybe could you just talk to us about the confidence from your side and the willingness from the customer side to start locking in that pricing and term instead of keeping contracts on short term? It looks like you're now extending that out and getting more contract coverage across your total fleet. Maybe just spend some time walking us through that. Well, there's several factors. One is, which has been talked about on reactivations. I mean, we wanna make certain that when we're reactivating a rig and, you know, these are $300,000, $400,000, $500,000 reactivation fees, and we wanna make certain that we're either getting some lump sum or we're getting some term coverage, you know, to cover that cost. I think in general, you know, customers are willing to lock in. I think part of the reason why they are is because of the efficiencies and the startups that our people are able to provide. I mean, you know, it's not unusual to see, you know, historically rigs start up and really struggle for several months. Our teams are doing a great job just starting right off the bat and in some cases even drilling record wells right out of the box. There's a lot of reason why customers are willing to enter into these term contracts. Again, we're gonna continue to push on pricing. It's a really tight market as it relates to super-spec availability in terms of anything being ready to go. I mean, there's really nothing ready to go right now. Everything's been idle for you know for well over a year. Does that answer your question? Yeah, very helpful. I appreciate it, guys. Thanks. Okay, thank you. We will take our next question from Ian Macpherson with Piper Sandler. Your line is now open. Hi, thank you. Hello, John and Mark. How are you? Hi, Ian. Good. Good. How are you? Great, thanks. I wanted to ask if we could peek a little bit past fiscal Q1 towards the trajectory of your margins in U.S., because we see with the more expensive reactivations, it looks like your average reactivation cost per rig day is more than doubling in this quarter. That should improve with time, with better absorption and a deceleration of those costs. You have your rates being pulled up, especially by the premiums you're getting on expensive upgrades for walking rigs. I would imagine those dynamics should point us towards a pretty good inflection in your average daily margins. I just wanna get more comfortable that you see that happening in fiscal Q2, or do you see cost pressures or other dynamics maybe pushing that out into a later point in the year? Well, appreciate the question, Ian. This, you know, it's, I think if I remember right, looking at consensus estimates, you know, had us adding 10 rigs in this quarter that we're giving guidance on, but we're gonna be adding three times that. There's a directional factor, the sheer volume of reactivation expenses with that, really heavy increase in activity. To your point, coupled with the fact that as I mentioned in prepared remarks, we're also getting ready this quarter, several rigs that'll actually commence work right after the turn of the calendar year. That's kind of loading in some extra. On a per rig basis, I think we'll be pretty consistent at the end of the day. As we look forward, we do expect the absence of that, you know, to be accretive. You know, it just depends on how you do the math, but you could see anywhere from $500- $1,000 at least per day accretion from the absence of that. So that's, you know, directionally it's looking good, for potential cash accretion, but there's gonna be a question mark there, and that is we still expect more rig accretion in the first calendar quarter. It's just too early to have clear line of sight through to March 31 what that volume will be. But then we expect that our customers, especially public company customers, will hold the line pretty steady and maintain these new budgets from April through September of next year. Yes, that's very helpful, Mark. That's all I have. Appreciate it, guys. Thank you. We will take our next question from Neil Mehta with Goldman Sachs. Your line is now open. Yeah, thanks, team, and appreciate the visibility on 2022 capital spending. I know that 2023 is a really far way away and it's hard to get visibility, but just how as we think about that CapEx budget, which was a little higher than consensus, how much of that is one-time-ish in nature? As you look at 2023, do you get more to a maintenance- type of program at which [audio distortion] cash flow comes through in a more powerful way? Does that make sense? Any color that you can provide on the long term as opposed to just next year? Thanks, Neil. Great question. There are several things to consider when you consider the question. I think we're back into that, you know, as I mentioned, historical 750,000-1 million active rig range. Where that might go through time, who knows for certain, but I hope it's a little bit more muted through time. We're experiencing the obvious inflation that we're including in guidance for this year related to steel costs, et cetera. Plus, we had really, if you will, taken a holiday from operating our FlexRig Machinery Center in the last calendar year, and we're having to get back in business, recertifying top drives, BOPs especially, et cetera. Kind of a crank up of work there that might normalize a bit through time as well. The big question mark is what do our customers wanna do related to walking rigs, as John and I went through a few moments ago. You know, we've had interestingly, in the churn of rigs this year, even though rig count stayed pretty steady and, you know, modestly increased in calendar Q2 and Q3. We had some customers that picked up skidding rigs and actually exited walking rigs, while other customers quickly absorbed those walking rigs. As has been evidenced by commitments, we're still seeing customers want our design of a walking rig and commit to those despite the availability of them in the broader market. It's really just gonna depend where as we move towards better term and better pricing for those commitments to get the right return on capital and the new investment, those can be easy decisions to make. It's just gonna depend, Neil, is that helpful? Well, I will add one thing. Let me just add one footnote, that corporate CapEx will come down. Once we get these IT projects done that shifted from year- to- year, they're done, and some of these real estate matters will be done as well. Yeah. That is helpful. We are all trying to figure out what normalized free cash flow power is. That's good clarity. On the positive side, I wanna talk about market share and your market share level is, I think it's up to 26% now, which is above historical levels. Just provide us your perspective on your ability to continue to maintain that market share. What are the key competitive threats that you're monitoring, and what confidence you can give to the market around your ability to sustain these type of levels? Well, Ian, fortunately, we've had a track record coming out of downturns where we capture market share. We fully expect that, at least, you know, the management team, the company in general, felt like we had the opportunity to do that. You know, it's interesting, over the last year, there's been about 235 net adds to the market, rig-wise, and 180 of those were from private companies. 75% of the adds were private companies. We're the largest, we still have the largest market share of the private company, and I think we're up to 16% of that share. But the public companies, of course, have only had 25% of that. We think it's probably going to go the other direction at least through Q4 and Q1, where we're gonna see at least based on the commitments that we have, about 60% of our commitments are public companies. There's a little bit of shift there. We've got about 31% of the public company market share. Our hope is that we can continue to gain share. You say, "Well, why is that and how can you continue to do that?" Well, I think a lot of it is part of what I've already touched on is the ability to start up safely and efficiently and being able to you know really hit the ground running. You know, we haven't talked about performance-based contracts this morning with the exception of the prepared remarks, but we have a lot of customers that are really interested in entering into win-win contracts. They see, just like we do, that the day rate contract really isn't structured to drive outperformance. Fortunately, we have customers that are willing to enter into those new types of contracts. I think that's a driver. I look at all the work that we've put in over the last four or five years, organizationally and just continuing to invest in our people and our systems and processes. We're utilizing data today better than we ever have, and that helps us in terms of driving better performance. I mean, at the end of the day, that's what our customers want, is they want better performance. They want obviously efficiency and reliability. Then there's an ESG component. Again, the data set that we have today and our ability, we believe, to be able to manage ESG at a better level than what our peers are going to be able to do. Again, I think those are some things and that are ahead that hopefully we can continue to take advantage of. Thank you, sir. Thank you. Thanks, Neil. We will take our next question from Scott Gruber with Citibank. Your line is open. Yes, good morning. Good morning, Scott. Good evening. Good point. How are you doing, Scott? Doing well. Quick Doing well. Quick follow-up on ADNOC. What's the vintage of the rigs being sold? It's just the restart CapEx and recertification could be somewhat deceiving when you're moving the rigs abroad, and then do you think there's an opportunity to sell more rigs to ADNOC down the road? Go ahead, John. Scott, we, you said vintage. Are you asking about rig type? Well, rig type and— is the main question, but if you wanna throw out a build year as well. Scott, I'll jump in on the rig, the vintage. You know, it varies across the eight, and there's less sort of recertification work that we're going to be doing for some of the componentry, and there's more sort of some of the technical spec work. Remember, two of the eight are super-spec, though. You know, a lot of this is really the cost to get some of the six to Houston and across the Atlantic Ocean, the Mediterranean into final destination. Yeah, that's the majority really of the expense is just getting them ready for international and just getting them over there. In terms of selling more rigs, we don't have plans to sell more rigs. We do have. We're gonna continue to put rigs to work in that way. We currently don't have any plans to sell them more. Got it. It's only two that are super-spec. Sorry, I think I heard that wrong. I was thinking it was two that were not super-spec, but it's only two that are super-spec. No. Correct. The two that are here are not super-spec, and then we're sending two over, and then the rest will be non-super-spec. Understood. Okay, that makes sense. With respect to the rest of the international portfolio, just to confirm that the four rigs going to work with YPF, those would be incremental in Argentina? Yes. There's one that's going to work this quarter that has been planned for a bit, and then there'll be one, I think, in fiscal Q2 and two in fiscal Q3. At this stage, that timing could be subject to change, but all the remaining three after this quarter are planned for this fiscal year. Got it. Starting to get a little bit of scale back in the Vaca Muerta operations there. That's some exciting news for the Argentina team. Oh, definitely. Just thoughts on potential incremental demand, you know, beyond what's contracted to go back to work in Argentina and Colombia, because after those go back, you still have a fair bit of spare capacity on the international side. You know, any color on additional rig adds over the course of 2022? I'll let John comment further on customer specifics, but we don't have anything definitive. However, I will tell you that we are participating in bidding activity in both Colombia and Argentina today. John? Yeah, that's right. We've seen interest pick up in both Argentina and Colombia. We've seen the big rig work in particular be of interest in Colombia and then, of course, Vaca Muerta with the gas plan that they recently put in place. It's resulting in some rigs going back to work in the Vaca Muerta. Excellent. I'll leave it there. Appreciate the color. Thank you. Thanks, Scott. We will take our next question from Taylor Zurcher with Tudor, Pickering. Your line is open. Hey, John and Mark. Thanks for taking my questions. First one, just wanted to circle back on cost in the lower 48. I mean, clearly some element of the cost increase is transitory with elevated reactivation costs, but a piece of that's gonna stick with you on the inflationary side. I was hoping you could help us understand, you know, if we just look on a per rig basis, where normalized costs are on a per rig basis after some of these reactivation costs temper down a bit in the back half of the year. I mean, are we at $15,000, $16,000 a day or a different range on a per rig basis? Taylor, thanks for the question. You know, there's a lot of moving parts in here. Besides reactivation costs, there's several things to consider. There's labor cost increases that we alluded to, which, you know, will be margin neutral, as we have customer protection provisions and contracts. You know, we also have, as we've moved away from our previously- harvested inventory, the quote-unquote, penny stock, we've talked about in prior quarters, and we're having to pull out a fully- costed inventory, you know, there are adjustments there. I will say, though, that, you know, I don't anticipate a lot of working capital lockup, for that sort of thing, as we have implemented a lot of processes, policies and systems improvements so that our warehouses are live in Oracle and people across the United States can see all the warehouses. We've put in place min-max programs to manage the amount of buying that we do. You know, nonetheless, we will still see a little bit of, you know, maintenance costs go up. But maintenance is not the largest component of OpEx as you know, labor is. I would say a guess is probably closer to $14,000 after all those moving parts. But we still have some time to go until we settle to the final number, I believe. Okay. Thanks for that. Just a quick follow-up on some of the smaller divestments you made in U.S. land, the partnership with Parker around TRS, and it sounds like you've also exited the trucking business. Can you just talk a little bit about what the benefits to H&P are in terms of why you decided to ultimately exit those businesses? I know they're not, you know, core to the lower 48 business, but do add some additional revenue margin per day to your rig business. Just curious if you could help us think about, you know, why you're exiting those businesses and what the benefits are to H&P? I'll start with a couple of the numbers things and let John expand otherwise. You know, as we look at these, we have approximate proceeds that are initially modest, $6 million-$7 million, which you'll be seeing coming out in our Form 10-K later today, plus the potential for more revenue sharing through time. You know, these are very much margin neutral, so there's not a lot of accretion to our day margin. If you think about it, they are very capital- intensive businesses. As we focus on our capital spend through time, that was one of our considerations. Then there's a bit of, you know, the just the time and attention that such margin- neutral businesses can bring for the management team. John? Yeah. Taylor, it's a great question. We've had both of those services for a long time. At the end of the day, if you get right down to it, we could not grow those to significant scale. We couldn't get the— We just continued to believe year- after- year that we would get the scale from the customer, from our customer base. I think it's just probably a function of the competitive nature out there for those particular services. But I think probably the biggest thing for us is it simplifies what we're doing. It removes some complication. You know, as you just think about, I mean, trucking, running trucking is very complex. As Mark said, it's capital intensive. There's a lot of training and risk that's different than rigs, and really kind of the same way with casing. It just really didn't fit our model. You know, we hated their— great both the trucking and the casing are best in class, there's no doubt about it. Again, it was very hard to grow it to the extent that we needed to. Yeah. Understood. Thanks for the answers, guys. Thank you. We will take our next question from Waqar Syed with ATB Capital Markets. Your line is open. Thank you for taking the question. John, in terms of the contracted day rates, comparing this quarter or Q3 calendar to Q2, you know, as you've added, you know, new rig contracts, has the contracted day rates gone up? Or, you know, if you look at maybe the forward calendar Q4, has the contracted day rate gone up sequentially, or is it still declined? Well, Waqar, as you know, we're working really hard to get out of the day rate business. Obviously, we, you know, we can back into it. If you were to look at it on a day rate basis and you pull out the term contracts that were entered into at an earlier date at much higher rates, then, yes, the quarter-over-quarter it is increasing. I don't know the amounts. Dave, that may be something that you can mention if you have that information. If you combine them all together because of the rigs that are rolling off of earlier term contracts that were much higher rates, that has a negative impact on the overall margin or overall margin and revenue. Just one other on the same topic. How does the contracted day rate for the 82 or so rigs that are in a contract compare to the spot day rate right now? Oh, that's a great question, Waqar. As we consider what John just said about some rigs rolling off that are signed on term in a better market than even our increasing day rate market that we have today, I think, you know, as we just alluded to with a marquee price of $25,000 per day for a walking rig conversion, that we're getting back to some better pricing levels. In fact, we've had four existing term contracts and the standing spot customers, we've been passing through rate increases. Those don't all take effect at the same time, and we're still in negotiations with some customers about what that exact rate increase will be and when it will be. Suffice it to say that, you know, we are pushing the pricing and more of that's gonna be to come. Dave, any specifics on any numbers? Yeah. Just to add, Waqar, on the pricing, it's very region-specific. There's a couple of regions where the d ifference between the spot and the term isn't that great, but then there's other regions, like in the West, where you're seeing still a disparity between the two, you know, a couple of thousand per day or something like that. Okay. John, just one last question, if I may ask you. You know, if we go back like different cycles, H&P has always had a premium margin over its competitors. However, that seems to have gone away and depending on how you treat the H&P technology contribution, it doesn't feel as if right now there is a premium for, you know, embedded in the numbers. Do you think that as the cycle, you know, as we continue into next year, that you regain that margin premium or is it going to be kind of more in line with where the competition is? Yeah. I think if you look at individual contracts that we win, we're winning at a premium. Obviously these costs that we have, the reactivation costs and other costs that we're incurring have caused some challenges. I think if you go back to the 2017, 2018, 2019 market, we did have a premium margin at that time. Yes, I fully expect that we'll continue to have premium margins over our peers. You mentioned technology. No doubt, technology is gonna play a larger role. You know, we're continuing to have adoption from customers. Again, we're continuing to work very hard on executing on new commercial models, performance-based and KPI. We have customers that love the model, and they're willing to pay for a lot of the value that we provide. More to come. We can talk about it all day. We just have to demonstrate it, right? I would just footnote, Waqar, that we're getting these with these upticks that we're guiding to and talking about in rig activity. We're starting to get back to absorption rates with our scale, which will help with that margin accretion and historical industry-leading margin. Okay. Great. Thank you very much. We l ook forward to that. Thank you. Thank you, Waqar. We are too. Brittany, was that our last question? That was our last question for today. I will turn the program back over to John Lindsay for any additional or closing remarks. Okay. Thank you, Brittany. Appreciate it. Thanks again, everybody, for joining us today. As mentioned, we're very optimistic about the future. We thank obviously our H&P FlexRigs, our digital solutions, and our best-in-class people. We're looking forward to the future and we'll talk to you next quarter. Thank you. This does conclude today's program. Thank you for your participation. You may disconnect at any time, and have a wonderful day.