Helmerich & Payne - Earnings Call - Q1 2021

Transcript

Speaker 0

Good day, everyone, and welcome to today's Helmerich and Payne's Fiscal First 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 be advised this call may be recorded.

It is now my pleasure to turn today's program over to Dave Wilson, Vice President. Dave, go ahead.

Speaker 1

Thank you, Christy, and welcome everyone to Helmerich and Payne's conference call and webcast for the 2021. With us today are John Lindsay, President and CEO and Mark Smith, Senior Vice President and CFO. Both John and Mark will be sharing some prepared 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 will include 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 actual outcomes and results could differ materially. You can learn more about these risks in our annual report on Form 10 ks, our quarterly reports on Form 10 Q and our other SEC filings. You should not place undue reliance on forward looking statements. We undertake no obligation to publicly update these forward looking statements.

We'll also be making reference to certain non GAAP financial measures such as segment operating income and other operating statistics. You will find the GAAP reconciliation comments and calculations in yesterday's press release. With that said, I'll turn the call over to John Lindsay.

Speaker 2

Good morning, everyone, and thank you for joining us today. With one month behind us in 2021, we find ourselves with a combined sense of relief and optimism, relieved that one of the most difficult years in the company's one hundred year history is behind us and optimistic considering the market share gains accomplished during the 2021 and strengthening oil prices, which enhance the financial health of our customers. We entered the new year with 94 rigs running in US land. That's double the number we had in August and the upward trend continues. Around this time last year, WTI prices were trading in the low fifties.

There were approximately 800 rigs operating in The US land market, and H and P was operating 194 of those rigs. Contrast that with today, where oil prices are up over 10% up into the upper fifties, and the industry rig count is approximately four fifteen rigs and H and P is running 103 flex rigs. Obviously, a lot has happened between, these two data points. And it shouldn't surprise anyone that the short and medium term activity outlook from E and P companies is taking a while to take shape. However, if market expectations for US production levels continue to drop, that should have a positive impact on oil prices, which further supports consensus expectations for approximately 500 active rigs in The US at year end.

Taking this step further, by our count, there are approximately six thirty super spec rigs available in The U. S. Market. Looking forward, we believe the vast majority of all working rigs drilling horizontal wells will continue to trend toward the super spec classification. And if activity does reach 500 rigs, the industry rig count would begin to approach utilization levels that have historically provided pricing power.

Today, we are hopeful and encouraged by the recent worldwide deployment of COVID nineteen vaccines. We're encouraged with an improving crude oil price picture. And we're encouraged by the progress we continue to make on strategic efforts to deploy additional digital technology solutions and to advance new commercial models. Even with the early success of vaccines for COVID nineteen, there remains a significant level of uncertainty regarding the global economic recovery as well as the changing political environment. And that certainly tempers our short term optimism.

While it's encouraging to see oil prices higher than expectations, we are cognizant that even in a stable or improving environment, there remain several challenges ahead for the industry. We are encouraged seeing the industry rig count begin to recover, but customers are still in the budgeting process to determine their capital allocation, and those levels will set the tone for activity during the remainder of 2021. We do expect public E and Ps to maintain financial discipline related

Speaker 3

to

Speaker 2

their announced budgets. We also expect private E and Ps to add rigs. However, we don't expect an outsized increase in fiscal 'twenty one rig count even if oil prices reach $60 per barrel. A return driven capital allocation strategy is in the

Speaker 4

best long term interest of our industry, and that's what we're aiming to support with our solutions based offering.

Speaker 2

H and P has a differentiated customer centric approach of combining our people, rigs, and leading edge automation technology, which enables us to deliver the highest value wells for our customers. An underlying principle of our performance contracts is the creation of a sustainable win win scenario based not only on efficiency but also by employing the advantages of automation related to wellbore quality and placement. Our patented drilling automation software is a key driver in improving well economics for the customer by enabling the drilling of consistently higher quality and better placed wellbores throughout the drilling program. To date, our autonomous auto slite technology is deployed on 25% to 30% of our flex rig fleet, And we currently have similar percentages for performance based contracts. Automation solutions improve the drilling efficiency of the well, but it also has a significant influence on the lifetime value of the asset by delivering a better wellbore to the completion phase, which will ultimately enhance production economics.

When successful, the combination of FlexRig and digital technology solutions leads to superior well economics by lowering risk and increasing returns for our customers as well as for H and P. We can't control the macro challenges, but we can remain laser focused on our technology solution deployment, our performance based contracts, and our value accretion for customers. We're encouraged that several customers have adopted these new solutions. But we recognize that more work is ahead and additional efforts aimed at change management must occur within the industry. Accordingly, improvements in technology solutions and performance based contract adoptions are not likely to be linear and may not always correlate with our rig count.

That said, we're seeing remarkable progress that's being made today. And we're steadfast and confident in our ability to lead and affect change in our industry. I'm very pleased with our people's service attitude and the ability to quickly respond to customer demand and improve activity by roughly 35% during the first fiscal quarter. Our market share today is back to pre pandemic levels. We are adding back more rigs in the competition due to our proven ability to reactivate rigs safely, efficiently, and cost effectively.

We believe there's an opportunity to grow our market share above 25%. If you look at previous downturns we have faced since the two thousand and eight financial crisis, we have emerged stronger with greater capability as we differentiated our offerings and grew market share in the premium part of the market. Going

Speaker 4

forward,

Speaker 2

in a structurally smaller U. S. Market, we believe super spec rigs combined with digital technology solutions that provide improved value through wellbore quality will prevail. Relative to the 800 rigs drilling a year ago, many idle SCR and less capable AC rigs may be permanently sidelined. Further, not all of our competitors with super spec rigs have the ability to enable the film automation features that many customers are beginning to require.

In the super spec classification segment, we have approximately 37% of The U. S. Capacity, with two thirty four super spec flex rigs that are unique with their digital technology capability across our uniform fleet. Another aspect of our asset deployment strategy we plan to execute will occur over the medium to long term in international markets. That strategy is to opportunistically reduce our US super spec concentration over time by deploying rigs internationally for appropriately scaled contracts.

Our international business development team is seeing some bidding activity in Argentina, Colombia, The Middle East, as well as other markets. At this time these prospects are in early stages, but we are encouraged by the customer interest in H and P FlexRigs due to a combination of our expertise in unconventional drilling, our strong historical performance in these areas, and the need for what we would consider an imminent legacy rig replacement driven by an evolution toward digital technology for wellbore quality and placement. These are great opportunities for H and P in addition to our initiatives to improve our cost structure where Mark will provide more details in his remarks. On the last call, we discussed having made investments in geothermal projects, and you may have seen some recent announcements by our strategic partners. Along with looking at emissions reducing opportunities like geothermal, H and P will continue to explore and invest in new and diversified technologies as well as expand our digital technology capabilities for the long term sustainability of the company.

Before turning the call over to Mark, I want to underscore once more the focus and success our company has made on its strategic objectives, particularly given the economic and industry headwinds we are navigating. As we've indicated previously, introducing disruptive technologies and new business models is a long, arduous, and sometimes unpredictable process. I believe our dedicated teams are well equipped and our conservative financial stewardship will enable us to capitalize on the challenges and opportunities ahead. And now I'll turn the call over to Mark Smith.

Speaker 3

Thank you, John. Today, I will review our fiscal first quarter twenty twenty one operating results, provide guidance for the second quarter, update full fiscal year 2021 guidance as appropriate, and comment on our financial position. Let me start with highlights for the recently completed first quarter ended 12/31/2020. The company generated quarterly revenues of $246,000,000 versus $2.00 $8,000,000 in the previous quarter. The quarterly increase in revenue was due to higher rig count activity in North America Solutions as operators resumed some drilling activity.

Total direct operating costs incurred were $200,000,000 for the first quarter versus 164,000,000 for the previous quarter. The sequential increase is attributable to the aforementioned additional rig count in the North America Solutions segment and the related rig recommissioning expenses. General and administrative expenses totaled $39,000,000 for the first quarter, higher than our previous quarter due to the resumption of short term incentive accruals for fiscal twenty twenty one, but within our guidance for full fiscal year 2021. During the first quarter, we closed on the sale of an offshore platform rig to its longstanding customer as per a provision in the original long term contract. The sale closed for consideration of $12,000,000 paid out over two years.

The rig had an aggregate net book value of $2,800,000 and the resulting gain of $9,200,000 is reported as a part of sale of assets on our consolidated statement of operations. In connection with the sale, we entered into a long term management contract for this rig in our Gulf Of Mexico segment. Our Q1 effective tax rate was approximately 19%, which is on the lower end of our guided range due to a discrete tax expense. To summarize this quarter's results, H and P incurred a loss of $0.66 per diluted share versus a loss of $0.55 in the previous quarter. First quarter earnings per share were positively impacted by a net $0.16 gain per share of select items as highlighted in our press release, including the aforementioned offshore rig disposition.

Absent these select items, adjusted diluted loss per share was $0.82 in the first fiscal quarter versus an adjusted $0.74 loss during the fourth fiscal quarter. Capital expenditures for the 2021 were $14,000,000 below our previous implied guidance. This is primarily due to the timing of spending, which has shifted to the remaining three quarters of the fiscal year. H and P consumed approximately $20,000,000 in operating cash flow during the 2021, in line with our expectations. I will have additional comments about our cash and working capital later in these prepared remarks.

Turning to our three segments, beginning with the North America Solutions segment. We averaged 81 contracted rigs during the first quarter, up from an average of 65 rigs in fiscal Q4. I will note here that at the end of fiscal Q1, all idle but contracted rigs, which I will refer to as IBC rigs thereafter, had returned to work compared to an average of approximately 15 IBC rigs in the previous quarter. During the first quarter, we doubled our rig activity from the prior quarter low of 47 active rigs. We exited the first fiscal quarter with 94 contracted rigs, which was slightly above our guidance expectations as demand for rigs continue to expand from the low reached midway through the end of the previous quarter.

Revenues were sequentially higher by $53,000,000 due to the previously mentioned activity increase. Included in this quarter's revenues were roughly $4,000,000 of unexpected early termination revenue from the cancellation of one rig contract. North America Solutions operating expenses increased $47,000,000 sequentially in the first quarter, primarily due to adding 25 rigs, a 35% increase in North America activity, as well as reactivating 10 idle but contracted rigs, both of which resulting in one time reactivation expenses of approximately $10,600,000 Looking ahead to the 2021 for North America Solutions. As I mentioned earlier, we exited Q1 with slightly more rigs contracted and running than expected. The activity level has continued to grow, albeit at a more moderate pace than the prior quarter as operators add rigs to maintain production levels with oil above $50 per barrel.

As of today's call, we have 103 rigs contracted with no IBC rigs remaining. We expect to end the 2021 with between one hundred and five and one hundred and ten contracted rigs. As John discussed, our performance contracts are gaining customer acceptance and of the approximately 34 rigs that we have added to the active H and P rig count after September today, more than a quarter are working under such performance contracts. In the North America Solutions segment, we expect gross margins to range between 60,000,000 to $70,000,000 with no early termination revenue expected. As we continue to add rigs, we will also incur related one time reactivation expenses.

Such expenses are expected to be approximately $6,000,000 in the second quarter. As we have seen in previous cycles, there is a correlation between the reactivation cost per rig and the length of time a rig has been idle. As a reminder, most of our rigs were stacked back in April 2020, nine months ago. Historical experience indicates that rig stacks for nine months or longer will incur cost of 400,000 to $500,000 to reactivate. Reactivation costs are incurred in the quarter of startup, so the absence of such cost in future quarters is margin accretive.

Our current revenue backlog from our North America Solutions fleet is roughly $448,000,000 for rigs under term contract, but importantly, this figure does not include additional margin that H and P can earn if performance contract criteria are met. Regarding our International Solutions segment, International Solutions business activity declined from five active rigs at the end of the fourth fiscal quarter to four active rigs at December 31. This decrease is the result of an expected rig release in Abu Dhabi due in large part to the disruption created by the ongoing COVID-nineteen pandemic. As we look toward the 2021 for international, our activity in Bahrain is holding steady with three rigs working. We also have one rig under contract in Argentina.

In the second quarter, we expect to have a loss of between 1,000,000 to $3,000,000 apart from any foreign exchange impacts as the legacy structural cost in Argentina continue to hamper international margins. Also, we still have a pending rig deployment in Colombia that continues to be delayed as our customer waits on required regulatory approvals to begin work. Turning to our offshore Gulf Of Mexico segment. We currently have four of our seven offshore platform rigs contracted and we have active management contracts on three customer owned rigs, one of which is on full active rate. Offshore generated a gross margin of $6,000,000 during the quarter, which was at the lower end of our estimates.

As we look toward the '1 for the offshore segment, we expect that offshore will generate between 6,000,000 to $9,000,000 of operating gross margin. Now let me look forward to the second fiscal quarter and update full fiscal year 2021 guidance as appropriate. Capital expenditures for the full fiscal 'twenty one year are still expected to range between 85 to $105,000,000 with remaining spend distributed over the last three fiscal quarters. Our expectations for general and administrative expenses for the full fiscal twenty twenty one year have not changed and remain at approximately $160,000,000 We also remain comfortable with the 19% to 24% range for estimated annual effective tax rate and do not anticipate incurring any significant cash tax in fiscal two thousand twenty one. The difference in effective tax versus statutory rate is related to permanent book to tax differences as well as state and foreign income taxes.

Now looking at our financial position. Humberg and Payne had cash and short term investments of approximately $524,000,000 at 12/31/2020 versus 577,000,000 at September 30. Including our revolving credit facility availability, our liquidity was approximately $1,300,000,000 Not included in the previously mentioned cash balance is approximately $35,000,000 of income taxes receivable and related interest that we collected after the end of the first fiscal quarter. Our debt to capital at quarter end was about 13% and our net cash position exceeds our outstanding bond. H and P's debt metrics continue to be a best in class measurement amongst our peer group that allows us to keep our focus on maximizing our long term position.

As a reminder, we have no debt maturing until 2025 and our credit rating remains investment grade. Now a couple of notes on working capital. Our trade accounts receivable at fiscal year end of $150,000,000 grew by $38,000,000 to approximately 188,000,000 due to the added rig activity as previously mentioned. The preponderance of our AR continues to be less than sixty days outstanding from billing date. Also included in AR is another approximately $10,000,000 of tax refund receivables.

Our inventory balances have declined approximately $5,000,000 sequentially from June from September 30 to $99,000,000 and we continue to leverage consumables across the entirety of U. S. Basins use and reduce inventory on hand. These efforts are resulting in better spending rationalizations that are reducing our out of pocket expenditures. Our accounts payable terms optimization project mentioned on the last earnings call will extend our payable terms with certain key vendors.

And finally of note are one, the majority of our annual ad valorem taxes accrued through the year are paid annually in the fourth calendar quarter. And two, the short term incentive compensation accruing for fiscal year 'twenty one will not be paid until the '2. As I mentioned on the November call, we expected to use a modest amount of cash on hand as we worked toward a 100 plus rig count activity level. As mentioned earlier in my comments, we arrived at a 100 rig count level during this second quarter. We believe at this activity level, our point forward quarterly operating earnings will fund our maintenance capital expenditures, debt service costs and dividends.

Based on our updated forecast, we expect to end fiscal twenty twenty one with cash and short term investments at or above $500,000,000 In closing, we are continuously working to manage our costs, both operating and SG and A expenses as well as capital expenditures. We believe active cost management is crucial in the now structurally smaller United States upstream market. Various initiatives are underway to identify and drive out costs where possible to enhance margins going forward. That concludes our prepared comments for the first fiscal quarter. Let me now turn the call over to Christy for questions.

Speaker 0

And we will take our first question from Tommy Moll with Stephens. Tommy, go ahead. Your line is open.

Speaker 4

Good morning and thanks for taking my questions.

Speaker 2

Good morning, Tommy.

Speaker 4

John, I wanted to start on performance based contracts for as long as you've been talking about that initiative. You've been very clear that it's not, it's not a change in the in this industry structure that's gonna happen overnight and that it's going to take some time. What context could you give us about how the downturn may have accelerated customer willingness to talk about new types of pricing models versus made it more difficult just given how stretched a lot of customers were. Maybe it was just not something that they were willing to engage in conversations with.

Speaker 2

Sure, Tommy. Good morning. You know, it's really you won't be surprised by this. It's really a mix. You know, every customer at this stage of the game probably views it a little bit a little bit differently.

I think there are some as a result of the downturn, as you mentioned. I I think it has accelerated their their thinking. They recognize as much as we do that the the industry really has to evolve. And so customer adoption of these new models are you know, it's it's it's different across the the board. I I think what we're encouraged by, though, is that, there are, you know, as as as we said in our remarks, you know, 25 to 30% of our rigs are under performance contracts or some new commercial type.

And I think the reason is by definition it's that performance based contract, it's a win win opportunity when you execute it properly. And it really delivers a higher level of value for the customer and at the end of the day for H and P as well. We have continued to stress that in order to be truly successful, it really has to be a partnership agreement with your your customer. And there's gotta be mutual trust. There's gotta be mutual respect.

And I think there also has to be an acknowledgment that, you know, each you know, we each have, strengths, and and there's areas that we can leverage those strengths for the betterment of the project. But taking it really, and this is where I think it's most valuable, and it really relates to our decision to have an approach more focused on solutions, overall solutions. Because we're, you know, we're combining our digital technology solutions. AutoSlide is the easiest one to talk about right now. But, you know, we're taking a focus and it's not that we're not still interested in taking a twenty day well to fifteen days or a fifteen day well to ten days.

We wanna do that. But we're also focusing on the lifetime value of the asset. You know, we're which our customers are doing that, but we haven't necessarily been engaged in that in that discussion. So as you think about wellbore quality and wellbore placement and the things that we're doing, we're really focusing on the lifetime value of that wellbore for the next ten or fifteen years. And I think that is is really drawing some attention.

Again, we're we're seeing some some opportunities to continue to grow these new models with our with our customers. As you can imagine, the the day rate, it's really hard. Our teams are doing a great job. They're out there selling the benefits. I think we're starting to see some results.

Speaker 4

Thank you, John. That's all very helpful. And as a follow-up, I just wanted to move to the topic of overall industry rig count. And I want to ask you to make a specific call on a number, but maybe just give us a sense of what the contour might look like based on your customer conversations. And so does it seem like decision making among customers has maybe been delayed a little bit?

In other words, maybe in a typical year, there would be better visibility into a full year drilling plan at a rough time frame in your mind versus this year. It just seems like there's a lot more uncertainty and that you may end up getting a better peek into what those plans look like later into this fiscal year than normal? Or do you feel like, based on your conversations, you have a pretty good sense of what your customer base will will be doing to to calibrate for the the full year drill plans.

Speaker 2

There's there's no doubt that, you know, the market obviously, once customers decided to to put rigs back to work, it moved very quickly. And, you know, we're as we've said in our remarks, we're we're pleased to be at a 103 rigs today. You know, I think our our low was 46 rigs, low active rigs, 46 rigs in December. So, you know, we still have this quarter ahead. We're at one zero three.

We we we, set a range of one zero five to one ten. Our goal is to hit one ten. Team's working hard. We wanna make certain we do that. But it is very hard to see, and you've heard me say this over over time for a long time, really depending on, regardless of the market.

It's hard to see much past three months. And so we do have some insight into April and May. But as you know, the bud budgets for the public E and Ps, they're not all final. And when you and I think when you start thinking about a ramp in activity, we shouldn't expect a ramp like we've seen since August. I think it's going to be a much lower increase.

The other really surprise to everybody is that oil WTI is as high as it is. I mean, it wasn't that long ago we were talking about $45 to hopefully gain to $50 So one of the ways that we've tried to think about it again, and thank you for not asking me to predict rig count. But if we have the the opportunity, and we do, we look at we look at sell side consensus and you look at, you know, their estimates out there of having 500 rigs running by the end of the calendar year. And I think that's I think that's possible. And if you think about it, that's not a long way from where we are today, and and you don't have to add a whole lot of rigs over the next eleven months to get there.

So I think, clearly, our customers are gonna remain disciplined. You know, what they're doing is in the best interest, of their companies and the best interest of of our, industry, I believe. And so we're gonna we're gonna see how that plays out. You know, we talked about the need to have a return driven capital allocation strategy. We think that's in the best interest of the long term outlook for the industry.

So hopefully, answered answered your question. I wish, I wish I could nail a number. I do think the rig count will continue to increase, but I do believe it will be at a much slower pace than what we've experienced over the last four or five months.

Speaker 4

Fair enough. Thank you, John.

Speaker 0

I'll turn

Speaker 2

it back. Thanks, Tommy.

Speaker 0

And we will take our next question from Ian Macpherson with Simmons. Ian, go ahead.

Speaker 5

Yes, thanks. Good morning, John and Mark and Dave. The thing that stood out to me initially was the improvement that you've guided for your North America cash margins for the segment profit divided by rig count for this quarter and even backing out the termination and reactivation expenses, which I think net out to kind of a wash quarter to quarter, it's a healthy improvement. This has been a big sort of debate point for you and peers as to where cash margins might ultimately trough out. And so John, just given your constructive framework that you see for tighter super spec utilization by the end of this year and maybe some pricing power stabilizing, maybe improving the low spot rates that we've seen and heard about, does that give you more confidence than maybe you had last quarter with regard to now having some visibility now to a true troughing in your cash margins?

And is that going to look somewhere close to what we see here with the second quarter guidance for margins?

Speaker 2

Well, I'm going to direct Mark towards the details, but I do think we are working hard. I mentioned earlier, we're working hard to retire the day rate, and we obviously have rigs that are rolling off of rolling off of term contract that works somewhat against us. But we're also, you know, working with customers to enter those rigs into performance based pricing, and and so that that's beneficial. I do think that we're seeing some uptake on that, which hopefully, again, helps us on the revenue side of the equation and ultimately generating better margins. Mark, what would you add?

Speaker 3

Thanks, John. Ian, several things to think about in there. You know, certainly, certainly, this quarter we just exited, we had some some pressure, obviously, from the recommissioning expenses. Another thing we had a little bit upward pressure on as well was you may have heard me talk about, quote, unquote, penny stock over the prior couple of quarters in the in the last calendar year. We've kind of gotten through that penny stock as we increased activity.

And as a consequence, we've begun really digging into our on hand average cost of inventory, which drives up which drives up M and S cost. We you know, it's also there's some just other things in there that are are moving around, not necessarily all all linear, but, increasing activity levels, you know, has a positive impact, on our fixed cost leverage that we really I think your comment on troughing out maybe potentially because we had gotten down to that 47 rig low point of activity, last quarter, but I mean, the previous quarter. So, you know, we're getting more, leverage there with this increased number of rigs. You know, we're still gonna have, reactivation expenses coming through, obviously. We we have a roll off on the revenue side of some term contracts, but, you know, obviously, helping that are the performance contracts that we are putting in place.

So, again, not all linear, a lot of moving parts. I think that, you know, in addition to all of that, as I mentioned, we're working on a lot of cost cost out initiatives as alternate. I'm not gonna go into a lot of details on those. But over the next couple of quarters, we we hope that those are, you know, additive in in each of the initiatives, and the aggregate helps take some cost out of the system. And then I guess just, you know, as I'm thinking out loud here, finally, there's a little bit of apples and oranges as we move through this last year and took, took what were two segments, legacy US land and HPT, and combine them into North America Solutions, you you pulled in some of that overhead cost from the legacy HPT.

So there's a little bit of increase in cost there. So a lot of moving parts. Ian, is that helpful?

Speaker 5

Very helpful. And at the end of the day, look, we have your your cash flow outlook for the year, which kind of pulls it together for us as well. So that's good. Thanks. I wanted to ask a follow-up, though, on the international side.

We've seen Argentina and Colombia, they went from a 100 plus rigs to zero last year, but we've they're they're upward back to probably 50 plus today. So wanted to get, John, your your your thoughts on how you can how you can or how you want to and aspire to participate in the continued recovery there in those historically very strategic markets for you internationally.

Speaker 2

Yes, Ian. I mean, we've been in in both countries, Argentina and Colombia for for a very long time, and we have a great personnel base, great people in country, great asset base in in both countries. And so, yeah, I think we're gonna we're gonna participate, in that. I mean, there's no doubt that, you know, we'll see some rates going back to work in both countries. But there there, you know, there are things that are, challenging that are, you know, not just not just the macro side.

There's other challenges we have. We're definitely interested. I think we have a great opportunity to put put rigs back to work. Mark, what would you what would you add? Just a couple of

Speaker 3

other comments, Ian. You know, some of those initial rigs, I think, we might have mentioned on a previous quarter call, were some some work overwork. And then also the equivalent of idle the contracted rigs as we had in The US going back to work that were parked for some operators. You know, as John said in his prepared remarks, we are seeing, you know, bidding and tendering activity in country currently. And, you know, the super spec rig that we had sent, goodness, was it eighteen months ago now down to Argentina?

Those some of those conversations we're in with folks are about the super spec capability. Again, as John alluded to about our kind of mid to long term international look, we really think that the super spec rig there, and potentially upgrading other rigs there through time, can really be beneficial to that market.

Speaker 2

Yeah. I think those the the international market in general, just to add on a little more color, you know, in The US, we've been undergoing this replacement cycle for well over fifteen years. And, you know, there are many, many countries that have still very old asset SCR, even some that are newer versions, you really look at it, particularly if you're gonna be drilling a a horizontal unconventional well, they're not ideally suited for that type of work. So I think that's why it puts us in a in a great position to grow internationally. We obviously have the capacity to move flex rigs out of The US.

I mean, we've obviously done that in in both countries we were talking about as well as The Middle East. We just we just need to get more scale. So we think the opportunities are there, and and I think, you know, with with the slowdown in activity that we've seen internationally, we're gonna see some pickup. There's usually, you know, six months, nine months delay in getting the international account back up.

Speaker 5

Got it. Great. Thanks, John. Thanks, Mark.

Speaker 2

Thanks, Ian.

Speaker 0

And we will take our next question from Sean Meakim with JPMorgan. Your line is open.

Speaker 6

Thank you. Hey, good morning. Good morning, Sean. So I'd like to maybe just talk a little bit more about how the market share in the rig count has been unfolding. What do you think it it means for your opportunities going forward?

So at current levels, the data suggests the five largest land drillers have only maybe 60% market share today. So smaller drillers seem to have an outsized share relative to their share of super spec supply. So would it be your stipulation that those small drillers have their super spec or their best approximations of super spec rigs probably mostly utilized at this point and the incremental capacity to be soaked up will be predominantly among the large drillers led by yourself?

Speaker 2

Well, Sean, you know, I I I don't recall seeing that as a as a data point. Dave or Mark may have some additional color on this. What I will say is, you know, if you look at the and let's face it. Most of the rigs that went back to work or a large portion of the rigs went back to work were in the Permian. And I think of the rigs that went back to work in the Permian, we we captured two thirds of that of that share.

So I'm a little surprised that it's at 60%. I think the five largest drillers own about 80% of the super spec capacity, but I'm not certain how that how that looks in terms of rigs that have gone back gone back to work. I do think there's there's much more to the story than just, the classification of the rig because what we're seeing is, again, more of a manufacturing type approach. If you really are looking at the premium end of the market, you know, you think about our our business, and and it's amazing the efficiencies that we've been able to drive, in our industry. But when you start getting to the efficiencies that we're at now, in order to get to that next level, you really need some automated solutions.

We're still relying heavily on human, decision making, and that decision making is is a twenty four seven decision making making process. So there's there's obviously opportunities to do to do better with software. And so I think the smaller companies are gonna are gonna be challenged even more, not only on the rig spec side of the equation, but on on that digital side of the equation. So, Dave, you did you have time to to look at your notes? Do you have any any follow-up on that or or what?

Speaker 1

Yeah. I I just I just follow-up on on over time, you know, with these smaller players don't have the the technology that some of the larger players have and that there's gonna be a differentiation even among the super spec rigs over time. And so I do think the larger players that have that technology are able to provide that value are gonna get get the lion's share, of the rigs.

Speaker 6

I appreciate that. And I think part of what I was trying to get at is to the extent that, you know, they've got their best rigs running at this point, you know, they tend to have small numbers, right, single digit numbers of these types of rigs that the larger drillers remaining with the remaining capacity, that would probably help your confidence around pricing progression that you'd have considering it could be likely to bid on future opportunities.

Speaker 2

Yeah. Sure. I think I think that's right. I think you you're making a great a great point there. I missed I missed

Speaker 7

part of

Speaker 6

the I apologize. Was kinda closing the loop late on that on that question. So then the other thing I was thinking about was with respect to private E and Ps, There have been a bit of a swing in demand coming back quicker, right, that's consistent with historical trends. And they potentially can be more of a swing later in the year if oil prices hold and they have some incremental cash flow. So, John, just, what are you seeing in terms of their uptake for super spec and the incremental automation and software solutions?

Is it or is it too early, or can we get a bit of a read on appetite for that part of your portfolio versus maybe where those types of operators would you say pre-twenty twenty?

Speaker 2

I tell you, I've been very pleased, with the response from the private companies, private equity, companies, small privates just in general. We have some very strong partnerships. And and in a couple of cases, you know, we've you know, whether they're two rigs, three rigs, or five rigs, we've got all of their rigs. They they're all in on on on the flex rig. They're all in on the the digital solutions.

You know, they're they're partners with us. You know, we've got some, as an example, in alpha and beta testing, we've got auto geo steering, and one of the private companies are working with us on that. So that's encouraging to see. You know, the question earlier about the downturn, I mean, let's face it. Downturns are that's that's a time for survival.

And so we're we're all trying to figure out how can we make our our businesses better and more durable. And so we're seeing that. Again, fortunately for H and P, it's not just on the small private side, private equity side as well. We're also seeing it, of course, with our larger publicly traded companies as well as supermajors. So we've very pleased with the response.

Speaker 6

I appreciate that. Thanks, John.

Speaker 2

Thank you.

Speaker 0

And we will take our next question from Taylor Zurcher with Tudor, Pickering, Holt. Your line is open.

Speaker 8

Hey, thanks and good morning. We've talked a lot about the continued adoption of these performance based models. And clearly, of these software solutions you're offering are a big piece of the value added there. But I wanted to touch on the hardware side of things that you've got, off the top of my head, I think somewhere in the 40s in terms of walking rigs in your fleet. If we look at the 30 ish percent of your fleet that's under performance based contracts today, is a big concentration of that with your walking rigs?

And do you have a target moving forward? Or do you

Speaker 9

need

Speaker 8

to increase the number of walking rigs to also increase notably the performance based percentage of your contracts? Or are those two kind of independent factors moving forward?

Speaker 2

It's really independent factor. We do still have some conversions in process. And on the on the walking side of the equation. But, you know, we've, you know, we've been very fortunate whether it's walking, whether it's flex three skid or or flex five, we've got really kind of across the board. Customers, have those rigs that really suit their, their well designs and and the pads that they're that they're building.

So there's there's really not any push towards one or the other on the performance side.

Speaker 8

Okay. And and with a a number of quarters of of some of these performance based models now in the books, Are you seeing any any customers, sort of accelerate the timeline where where you relook at at the underlying KPIs in these contracts? Is that sort of a still an evolving process right now?

Speaker 2

You know, it's it's really evolving. I know there's continued, it seems like concern and angst over kinda resetting the bar. And I and I think it kinda goes back to my my earlier comments related to, you know, building strong partnerships and having mutual trust and recognizing and acknowledging the strengths that each brings to the brings to the party. And, I mean, at the end of the day, if we're able to deliver better performance than they can working with brand x, y, or z, then, that's that's great for for them, and it's great for us. And so we really haven't seen, that much.

We again, we recognize it as being a, as being a risk. But, you know, at this stage of game, we're not overly concerned. Mark, did you have something you wanna mention?

Speaker 3

Yeah. Just I would add, John, that, you know, for some of those customers who've been with us on the journey longer and are early adopters of the performance contract, they've seen the full effect of the use of the technology, and the improvement on the wellbore quality along the way. So what what that does is that enables us to go to a a completely different set of goalposts over time, Taylor, and that is looking at quality of the well. So if you think about, you know, the overall spread cost to build a well and think of the pie shape, you know, we're a slice of pie for our drilling cost. Completions are half a pie.

And if a if a if a less torturous wellbore can can be completed and fracked more easily and reduce the cost of that part, well, that's a a a certain total cost of ownership benefit for our customer, that we can participate in. So we're working with some customers on finding things, such things as tortuosity index and and trying to move to a different set of goalposts and get off of the get off of the efficiency treadmill.

Speaker 8

Got it. That makes sense. Thanks for the answers.

Speaker 2

Thank you.

Speaker 3

Chris,

Speaker 1

did we lose? Chris, do we have any more in the queue?

Speaker 0

Yes, have Waqar Syed. Your line is open.

Speaker 9

Okay. Thanks for taking my question. Couple of things. First of all, are you seeing any input cost inflation, whether in trucking or for steel, or in drill pipe or anything like that?

Speaker 3

Well, Kara, morning. And no. Not not not yet. Now, obviously, steel prices have increased this last year, as we know. But we we have a we have a a lot of extra component in our system from spares and from our previous ramp up in rig rig activity before this downturn that that we've discussed previously.

So we we haven't had to, we haven't had to buy anything new to, to to deal with the increased deal cost. Having said that, I I definitely see through time, I think this will hit us probably more in fiscal twenty two than when we get to to to the next round of of tubular replacements that, that that certainly could come into play. But through the rest of the system, no. We haven't seen any any inflationary pressures.

Speaker 9

Good. Good. And then just my last question in terms of you mentioned number of tenders on the international market right now. When are right now, what are they telling you in terms of when these contracts would would, I mean, actually start up, fully recognizing that international things keep you know, tend to get pushed to the right?

Speaker 3

Well, as, as John said in his prepared remarks, we do see that tendering activity in its early days. But just to your to your point and and John's comment, there's no no certainty on that stuff now because some of these tenders we've we've we've bid on actually, when the bid date comes and everything's finished, then guess what? The date gets pushed to the right, and you you rebid it again. But the good news is that that that potential deal flow is is is coming through, whereas this time last year, it it was not. So, that's that's an improvement in the right direction.

I think as we get more certainty around, you know, the vaccine rollout and and, in the next, you know, post, hopefully, COVID world, that that we should see that open up a bit more when when demand is more fulsome.

Speaker 9

So just like for for the second half, let's say, second half calendar year of 2021, do you think you'll have more rigs incremental rigs active in LatAm or in Middle East or same for both?

Speaker 0

Get it off.

Speaker 2

Wakar, we're sure we're sure hopeful. You know, I you know, what is it? There's there's so many things that, as we've said, there's still uncertainty out there. Things are definitely looking better. And, you know, with the lag time that we generally see with international, I think your timing is is spot on.

We just we just hope that things keep moving the the direction that they are, and we were able to close on some of the deals that we think we can close on.

Speaker 9

Thank you very much.

Speaker 2

Thanks, Riccard.

Speaker 0

And we will take our next question from Scott Gruber with Citigroup. Scott, your line is open.

Speaker 2

Hey, Scott. We can't hear you, Scott, if you're if you're on there.

Speaker 7

Are you able to hear me now?

Speaker 2

Yep.

Speaker 7

I'm sorry about that. Morning. Mark, are you going say in the performance contracts and the bonuses that receive under them, how much did that benefit fiscal 1Q margin? And more importantly, assuming a similar achievement rate going forward, does the performance bonus potential improve in the quarters ahead on per day basis? And if so, any color on how much?

Speaker 3

I've got that you know, we haven't we haven't really quantified that publicly, historically. But I I'll tell you what it it just anecdotally, if you if you look at some of the term contract rollovers we've had, and so basically going back in time a year to to previous spot rates, Spot rates in the market are obviously lower today, but what these performance kickers allow us to do is really kind of bring that is bridge that gap, if you will, between the two. So that's, that's been it's certainly been, margin accretive to us and equally beneficial to our to our customers' cost as well.

Speaker 7

Gotcha. But any color on, you know, whether that kind of opportunity I know you you're putting more contracts in place, but I guess is the margin benefit from them improving going forward or kinda static at this point?

Speaker 3

It's a it's a customer by customer relationship, by specific customer need, basis. So it's it's a it's if you look at these performance contracts we have in the portfolio, there's no pure linear, derivation that can be had with them. I think it's really you know, it's it's as John's been talking about, it's it's the solutions based approach. And so each set of KPIs is is different for for each unique customer and the pad they're on and the things that they need to accomplish.

Speaker 7

Got it. That was it for me. Appreciate the color, Mark.

Speaker 2

Thank you. Thank you.

Speaker 0

This does conclude our question and answer session for today. I will now turn the program back over to our presenters for any additional or closing remarks.

Speaker 2

Thank you, Christy, and thanks again to all of you for joining us today. As we have touched on during this call, there are many challenges ahead. However, we believe H and P is in a strong position to take advantage of these opportunities. We recognize that the only sustainable way forward is for our industry to continue to evolve. And we are approaching that change with our customer centric approach, which includes digital technology, performance solutions, and an equitable sharing of created value.

So thank you again for joining us today. Have a great day.

Speaker 0

This does conclude today's program. We appreciate your participation. You may disconnect at any time.