Good day, everyone, and welcome to the EOG Resources Fourth Quarter and Full Year 2021 Annual Results Conference Call. As a reminder, this call is being recorded. At this time, for opening remarks and introductions, I would like to turn the call over to Chief Financial Officer of EOG Resources, Mr. Tim Driggers. Please go ahead, sir.

Good morning, and thanks for joining us. This conference call includes forward-looking statements. Factors that could cause our actual results to differ materially from those in our forward-looking statements have been outlined in the earnings release and EOG's SEC filings. This conference call also contains certain non-GAAP financial measures. Definitions and reconciliations schedules for those non-GAAP measures can be found on the EOG's website. Some of the reserve estimates on this conference call may include estimated potential reserves and estimated resource potential not necessarily calculated in accordance with the SEC's reserve reporting guidelines. Participating on the call this morning are Ezra Yacob, Chief Executive Officer; Billy Helms, President and Chief Operating Officer; Ken Boedeker, EVP, Exploration and Production; Jeff Leitzell, EVB, Exploration and Production; Lance Terveen, Senior VP, Marketing; and David Streit, VP, Investor & Public Relations. Here's Ezra.

Thanks, Tim. Good morning, everyone. 2021 was a record-setting year for EOG. We earned record net income of $4.7 billion, generated a record $5.5 billion of free cash flow, which funded record cash return of $2.7 billion to shareholders. We doubled our regular dividend rate and paid 2 special dividends, paying out about 30% of cash from operations. And we are continuing to deliver on our free cash flow priorities this year with an additional special dividend announced yesterday of $1 per share. The last time we set an earnings record was in 2014. We earned $5.32 per share while oil averaged $93. Last year, we shattered that record earning $7.09 per share with $68 oil. That's 50% higher earnings with a 27% lower oil price. The catalyst for that improvement was our shift to premium 6 years ago. Premium is our internal investment hurdle rate that uses low fixed commodity prices to calculate the returns that drive our capital allocation decisions, $40 and $2.50 natural gas for the life of the well. While our premium strategy ensures high well-level returns and quick payouts in any given year, the more significant and durable impact is to our full-cycle development costs. The benefit of making investment decisions using fixed low commodity prices has the enduring impact of steadily improving corporate level operating and cash margins over time. That impact is now directly observable on the face of our financial statements. And last year, we raised the bar again to double premium. Our hurdle rate increased from 30% to a minimum of 60% direct after-tax rate of return using the same low fixed prices of $40 oil and $2.50 natural gas. The switch promises to further improve financial performance in the years ahead and is what gives us great confidence in our…

Thanks, Ezra. EOG generated record financial results in the fourth quarter with adjusted earnings of $1.8 billion and free cash flow of $2 billion. Capital expenditures of $1.1 billion were right in line with our forecast while production volumes finished above target. For the full year, adjusted earnings were a record $5 billion or $8.61 per share. This yielded return on capital employed of 23%, while oil prices for the year averaged $68 per barrel. Perhaps most important than setting records is what drove our outperformance. 2021 illustrated EOG's success at driving down our cost structure. ROCE would have been 10% or better at oil prices as low as $44. Keep in mind that back in 2016, when the premium investment standard was introduced, the oil price required for 10% ROCE was in excess of $80 per barrel. The dramatic improvements will be made to the profitability of our business reflect the benefits of using the highest investment threshold in the industry. The bottom line financial impact of double premium is just beginning to show up. But like our original switch to premium, it will grow over the coming years. Our goal is to position the company to earn economic returns at the bottom of the cycle, less than $40 oil and generate returns that are better than the broader market on a full cycle basis. Free cash flow in 2021 was a record $5.5 billion, and we deployed this cash consistent with our long-standing free cash flow priorities. We doubled the regular dividend rate, which now stands at an annual $3 per share and represents a 2.7% yield at the current share price. We are confident in the sustainability of our high-return low cost business model to support a dividend that has never been cut or suspended in this…

Thanks, Tim. First, I want to thank all of our employees for their outstanding accomplishments and stellar execution last year. I'm especially proud of their safety performance. In addition to outstanding operations and financial improvements, we achieved a record low innovate and find opportunities to increase efficiencies and lowered the average well cost by 7%, beating the 5% target we set at the start of the year. Our drilling teams are achieving targeted depths faster with lower cost by focusing on reliability of the tools and technical procedures that drive daily performance. For example, in our Delaware Basin Wolfcamp play, our teams have improved days to drill by 42% since 2018. In our Eagle Ford oil play, after drilling several thousand wells, our teams continue to refine the drilling operation to drive consistent performance for our rig fleet, resulting in a 21% reduction in the drilling costs since 2018. And with our decentralized organization and collaborative teamwork across operational areas, we continue to generate ideas for improvement through our innovative approach to areas such as improved bit design and drilling motor performance and share them throughout the company. On the completion side, we made great starts to expand the use of our Super Zipper or simo-frac technique to about one-third of our wells completed last year. Completion costs also benefited from reduced sand and water cost through our integrated self-sourcing efforts and water reuse infrastructure. Utilizing local sand and water pipelines includes the added benefit of removing trucks from the row of contributing to a safer oilfield with lower emissions. Cash operating costs were in line with forecast. And while delivering a higher level of total production, they were nearly equivalent to our cash operating cost pre-pandemic in 2019. The savings are a result of a focus on reducing workover…

Thanks, Billy. Last year, we replaced more than 2x what we produced and reduced our finding and development costs by 17%. Our permanent shift to premium drilling and focus on efficiencies driven by innovation and our unique culture ease to why our capital efficiency continues to improve, and our corporate finding costs and DD&A rate continue to decline. Our 2021 reserve replacement was 208% for a finding and development cost of just $5.81 per barrel of oil equivalent, excluding revisions due to commodity price changes. Since 2014, prior to the last downturn and the implementation of our premium strategy, we have reduced finding and development costs by more than 55%. With our double premium standard and the high grading of our future development schedule, we grew our reserve base in 2021 by over 500 million barrels of oil equivalent for total booked reserves of over 3.7 billion barrels of oil equivalent. This represents a 16% increase in reserves year-over-year. In terms of future well locations, we added over 700 net double premium locations across multiple basins to our inventory in 2021, replacing the 410 drilled last year by 170%. Our double premium inventory is growing faster than we drill it, and the quality of the locations we are adding to the inventory is improving. Innovation continues to drive sustainable cost improvements and operational efficiencies. And when you combine that with our focus on developing higher quality rock, we further improve the median return of the portfolio. We don't need more inventory. We are focused on improving our inventory quality. With this in mind, our double premium inventory now accounts for 6,000 of the 11,500 total premium locations in our inventory, representing more than 11 years of drilling at the current pace. Now let me turn the call back to Ezra.

Thanks, Ken. In conclusion, I'd like to note the following important takeaways. First, investment decisions based on a low commodity price puts the emphasis on full cycle cost of development and demands efficient use of capital. While the benefits of such discipline are realized immediately, the larger impact builds over time. The seed to our stellar results in 2021 was the premium strategy established 6 years ago, and we have set the stage for the next step change in financial performance by instituting double premium last year. Second, we are confident EOG's innovative and technology-driven culture can offset inflationary pressures this year. Our disciplined capital plan is focused on high return reinvestment to continue improving our margins in not only 2022 but in future years as well. Third, we are committed to returning cash to shareholders. We demonstrated this through the return of nearly 50% of free cash flow last year, and this quarter's special dividend are third in less than a year. Doubling our regular dividend rate indicates our confidence in the durability of our future performance. The regular dividend is our preferred method to return cash to shareholders. And as we continue to increase the capital efficiency of EOG through low-cost operations and improved well performance, growth of the regular dividend will remain a priority. We truly believe the best is yet to come. Going forward as a company and an industry with a financial profile more competitive than ever with the broader market and a growing recognition of the value we bring to society, EOG has never been better positioned to generate significant long-term shareholder value. Thanks for listening. Now we'll go to Q&A.

[Operator Instructions] Our first question today comes from Paul Cheng from Scotiabank. Please go ahead. The line is yours.

First, we have been asked by many that with your CapEx plan and your production profile, if the current commodity price hold by mid-year, will you change the pan or that under what circumstances that, that plan may get revised? That's the first question. The second question is that in your future capital allocation, is 2022 the way how you will be a reasonable proxy in the future? Or we will see the percentage in the new domestic drilling, which is about 10% this year and also that the facility and the gathering and processing, those percentage will go up as a total percent of your CapEx as you're trying to prove up more new resource area?

Yes. Paul, this is Ezra. I'll answer the first question, and then I'll hand the second question over here to Billy to answer for you. With regards to our plan this year, as we've talked about, the way we're approaching our planning is not based on the oil price that we're seeing. We're really looking to see the broad market fundamentals that are underlying and supporting that oil price and other macroeconomic indicators. So when we look at our '22 plan, we think we've designed a very high-return capital program. It balances our free cash flow this year with increased free cash flow in future years. And it really starts with investing in the double premium wells. When we bring those low-cost reserves into the company's financials, it helps drive down the cost basis of the company and it continues to expand the margins. It's what allows us to continue delivering high corporate level returns as well as increase the cash flow potential of the company, and that further supports our free cash flow priorities. So the program this year is at a pace that allowed us to capture and incorporate technical learnings to continue to improve each of our assets. And that's the most important thing that we look to do every year, not only in 2022, but to go forward into future years as well. And I'll turn it over to Billy to answer the second part of the question.

Yes, Paul. On the second part of the question, going forward beyond 2022 and the percent we have allocated to new domestic drilling potential or really our exploration plays and infrastructure spend, it's been fairly consistent in the past and I expect it to be fairly consistent going forward. The largest amount of our CapEx spend will always be dedicated to our more developing -- development plays like the Delaware Basin play. And then going forward, we remain excited about the exploration potential we see in many of our new emerging plays. And we'll continue to fund those at a pace where we can continue to learn and get better just as Ezra mentioned. The infrastructure spend has always been about the same percentage each year, and I expect that will continue to be managed in the same way. We want to make sure that we get too far out in front with the infrastructure spending, but it's done at a pace commensurate with the development activity in a given area. So I expect that will continue to be the case.

Our next question today comes from Arun Jayaram from JPMorgan Securities. Please go ahead. Your line is now open.

Yes. Global gas is clearly in focus right now. So I wanted to get your thoughts on the revamped agreement with which will provide you more linkage to JKM. I think today, you're selling about 140,000 MMBtu, and that increases to 420 over time. I was wondering if you could give us a sense of timing and shed some light on the type of realizations you get from marketing the gas to LNG? And how is the economic rent shared amongst you and

Arun, this is Lance. I was just saying good morning. We're very excited about the new amendment that we have with And you're exactly right. I mean, we've got thousands that started in 2020. And I think that just really speaks to being really a first move or 2 because as you can see right now, you can look at the price realizations, you can see JKM spot prices are near $40, having that first-mover capability, moving quickly there to get that exposure is exactly right. As you mentioned in your question, it's been very impactful in a positive way as we think about our price realizations. We're very excited about the commitment. You're right, it ramps up. So we've got the 140 today that will ramp to 420 as they go into service. That's estimated to be probably with the first -- for Stage 3 in 2026. But if you remember there, we ramp up. We kind of go to the $140 today we started into the 420 as Stage 3 goes into service. And we still will maintain and we extended the 300,000 MMBtu a day sell that we have that's linked to Henry Hub. So we're excited about it. It's a brownfield facility. They've demonstrated being early on many of their projects. So we're excited to see our relationship grow from that standpoint and expect to see the price realizations materialize as well.

And my follow-up is just on the 2022 program. Ezra, you guided to 570 net wells, we want to get a bit more color on the decision to allocate more capital to the Delaware versus Eagle Ford? It looks like your Eagle Ford activity will be down, call it, more than 50% year-over-year, while your Delaware will be up 30% more, including a little bit more second bone activity. So I was wondering if you could give us a little bit of color there.

Yes. Arun, this is Billy Helms. So yes, we're allocating a little bit more money to the Delaware Basin. And it's really just a function of the maturity of the Eagle Ford at this point. The Eagle Ford has been an active play for more than, I guess, 12 years and certainly has been a highly economic play for the company and continues to be. I would remind everybody that last year was the single best returns we've ever generated in the Eagle Ford play since its inception 12 years ago. And so it's still a very valuable play, but it is more mature. The Delaware Basin on the other hand is still a lot earlier in its maturity in this life cycle and still has a lot of opportunity to grow and test new horizons and expand our development capabilities over time. So it's just a lot younger in its maturity phase. So I think it naturally will command a little bit more activity on that side.

Our next question today comes from Doug Leggate from Bank of America. Please go ahead. The line is yours.

Last time I spoke to you, you were talking about the mix of the double premium wells in the production profile and of course the impact on sustaining capital and breakeven oil prices. So I wonder if you could just walk us through how you see that? The 32 breakeven you've given us today obviously comes with a, I guess, some element of growth in the capital. So how do you see the sustaining capital? How do you see that breakeven trending? That's my first question.

Yes. Doug, this is Ezra. Thanks for the question. Yes, our maintenance capital on the back of a 7% well cost reduction last year and then additional well improvement, combined with increasing the percentage of double premium wells. And what I mean by that is a lower cost of the reserves, bringing those into the company's financials. Our maintenance capital continues to decrease, which is fantastic for us. You're right, the $32 breakeven that we provided today is actually with our commensurate with the CapEx program that we have for this year. But the double premium wells, we can't stress enough. Not only is it -- does the impact show out on very rapid payout and a high rate of return, but really by bringing those lower-cost reserves and a lower decline into the base of the company, over time, it really does start to show up an impact the full cycle returns and free cash flow generation potential of the company in the future.

So where do you think those 2 numbers are today, the sustaining capital and the ex-growth breakeven?

Yes. So we didn't release a maintenance capital this earnings call due to the fact that we've started to allocate some additional capital into the Dorado play. And so it starts to get a little bit messy as you start going from oil into a BOE equivalent as we are starting to see the phenomenal results there with the Dorado play as we dedicate additional capital to it. Nevertheless, I think what we've outlined is with the 7% well cost reduction and slight improvements on the well mix year-over-year, we've continued to drive down that breakeven. And for the full cycle return, we have a slide in our deck that shows the one way that we like to present it is the price required for a 10% return on capital employed. And you can see we made a big step change last year as we drove that price down to $44.

My follow-up is a capital allocation question, and it's really -- maybe it's for Tim. The free cash flow you're showing in your slide deck of north of $4 billion a year after the special could essentially wipe out the majority of your share buyback authorization. I'm just wondering why you still feel no need to offer some kind of capital return framework? Because clearly, with the transparency of that breakeven level with the duration of your inventory and so on, valuation becomes a little bit more transparent. Therefore, buybacks could perhaps be more justifiable. So I'm just curious why you've been reluctant now to go down that route? I'll leave it there.

Yes. Doug, this is Ezra again. Just to reiterate our free cash flow priorities, first, the commitment begins with the sustainable dividend growth of our regular dividend. In '21, we doubled that regular dividend. And to us, that regular dividend is really indicative of what we're trying to accomplish. It reflects the continuing increase in the go-forward capital efficiency of the company. And it's also focused on creating through-the-cycle value and free cash flow, and that's ultimately what we're trying to do. Again, going back to what we were just talking about with the investment in the double premium wells and lowering the cost base of the company, trying to take at least a small step away from the inevitable commodity price cycles of our industry. The second free cash flow priority for us is a pristine balance sheet, which obviously provides tremendous competitive advantage in a cyclical industry. And then the third, what we're talking about right now is the additional cash return in the form of specials or opportunistic repurchases. And as we talked about, last year, we demonstrated the commitment with $2.7 billion in cash return through the form of $3 per share special dividends and are regular. And then we also retired that $750 million bond early in the year. In general, what we've talked about is we're going to use our -- reserve our repurchase opportunities to be more opportunistic than programmatic. So in times one way to think is that in times of rising share or oil price, you can expect us to prefer to do special dividends. And really, the way that we think about the share repurchase is, we measure it as an investment the same as we measure any investments across our business. So we want to make sure that it competes on a returns basis. And that's why we still prefer in an environment like this to stick with the special dividend as the priority for additional cash return.

Our next question today comes from Scott Gruber from Citigroup. Please go ahead. Your line is open.

Just following on that line of questioning, given that your net debt negative here at the start of the year, should we think about the cash build is largely being over This is Tim. No. First of all, we are excited to have to be in a position where we are to have a cash balance going -- our net cash balance going forward. So we will continue, as I said in my opening remarks, we'll continue to build cash on the balance sheet during these high oil price scenarios and look to -- for opportunities in the countercyclical times to deploy that cash in a meaningful way in the form of more specials or stock buybacks or just opportunistic things that come along in the countercyclical environment. So the answer, again, is no, we will be -- in these high price environment, we will be building more cash on the balance sheet.

Got you. I appreciate the clarification. And then congrats on the expanded export agreement. Just thinking about the broader backdrop here, there's likely another round of LNG project sanctioning along the Gulf Coast. It seems like the industry is in an advantaged position there. How aggressive EOG on entering additional agreements, thinking kind of similar terms? Do you guys foresee and expanded JKM to Henry Hub spread that you'd want to capture? Do you think that's sustainable and you want to capture that spread? Or do you kind of look at additional agreements more through traditional diversification lens?

Yes, Scott. Thanks for your question. This is Lance. I think what I can really point you to is like you think about each of our operating areas and you think about our transportation positions that we have, it really puts us: one, we're in close proximity; but two, we have the capability that we can transact very quickly. So I think first, I would point you to that. And then I'd say secondly, yes, we're always interested in new opportunities. So we'll be continuing to look at that from like a business development standpoint. And it's really going to be commensurate like you heard from Billy as you talk about -- as you think about growth, our volumes. And then as we move forward, we will be looking at new opportunities, but that will be definitely commensurate with our plans on a go forward as we look at our plan.

Our next question today comes from Neal Dingmann from Truist Securities. Please go ahead. The line is yours.

Maybe for you or Tim, maybe just ask one more on the shareholder return. I know most popular question. But you guys continue now to pay out over 50% of your free cash flow. And I'm just wondering on a go forward, I know there were some out there thinking you all would even have potentially a higher payout, is that something that you're targeting? I know you're not going to have the exact metrics on how you want to pay out up to a certain amount. But is that something internally you're always continuing to sort of look at paying out over 50% or 60% or something like that on a go forward, given your strong free cash flow?

Yes. This is Ezra. We continue to evaluate our cash position with respect to dividends on a quarterly basis. And what I would say is that, you're correct, we're thrilled to be in the position where we are, where we can offer to the shareholders such a competitive regular base dividend that again, I think, is our number one priority as a way to create value through the cycles. But on top of that, we are in a great position to offer continued strength of our balance sheet to support that dividend and then continue to offer cash return -- additional cash return of excess free cash flow in the form of these specials and buybacks. We don't have a specific target that we do. We stay away from providing a formula because we want to be able to have the flexibility to do the right thing at the right time to really maximize the shareholder value in a way that is protected through the cycles. Said another way, I think we've demonstrated that over the past year. We've taken the opportunity to both strengthen the balance sheet last year. And again, last year pay out a significant amount, $2.7 billion in cash returns. And we've doubled down on that basically with this first quarter announcement with the $1.75 per share cash return this quarter. And essentially, that reflects the evaluation, the positive commodity price environment that we were experiencing in and the strength of the underlying business and our confidence in it going forward.

I notice a nice bump on the NGL guide. Maybe could you talk about it -- I've seen you obviously now have a number of wells up in the sort of liquids area. Is that what's driving the growth there? Or can you could talk about sort of plans in the Marcellus side area or area, I would say,

Yes. We actually divested of our Marcellus position a couple of years ago that was in a dry gas part of the Marcellus acreage there in Pennsylvania. With respect to some of the other opportunities that we haven't really discussed publicly, that's really exploration, as you guys know. First and foremost, we're an exploration company. We're always striving to be a first mover and organically improve the quality of our inventory. So I will provide you a little bit of color on that. Domestically, we continue to explore across the U.S., our exploration program that we've talked about for the last year or so has been progressing. We finished last year drilling 12 wells across multiple opportunities, all dominantly oil-focused and we'll be slightly increasing that number this year to about 20 as we're encouraged with some of the results that we had last year. In general, though, like I said, we don't discuss the details of the exploration other than just to say that the opportunities are low-cost entry, they're oil focused, they're reservoirs that we think can exploit with our horizontal drilling and completions expertise. And this year, we look forward to doing some more delineation and appraisal drilling. And as we've said in the past, the goal of our exploration program is not just to find oil or find reserves. It's really to add to the quality of our inventory from a lower finding cost and higher returns perspective. And so it takes time to be able to evaluate that we can actually discover these opportunities and bring them into the mix where they're really going to help lower the cost base of the company and be a significant contributor to our portfolio going forward.

And I guess just a follow-up on that. As far as the NGL guide going up, that's simply a function of the fact that we have opportunity to make an election as to how much we recover or reject going forward on several of our processing contracts -- and with the strength of much of the NGL pricing, we're simply assuming we'll be in recovery mode more than rejection mode in several of those contracts this year.

Our next question today comes from Scott Hanold from RBC Capital Markets. Please go ahead. The line is yours.

And maybe just since you talked a little bit about the exploration opportunities in the U.S. Can you give us a sense of how you think about international exploration opportunities? I know you all were doing some work in Oman in offshore Australia. Is there any update there? And how do you think about international versus onshore or U.S. opportunities?

Yes. Scott, in general, as we've talked about, the international opportunities have -- they have a higher hurdle to really be considered additive to the quality of our inventory simply because we need to have access to services there. We need to have access to contracts, and we need to find the subsurface geology that actually makes it, not just competitive, but really superior to much of what we're drilling here. In Australia, to start with that one, we still have that opportunity. We plan -- we're in the permitting phase currently, and we plan to initiate drilling in that one early next year. And then in Oman, we did announce, as you recall, we had a low cost of entry into Oman. It included a 2-well commitment. And during the second half of '21, we drilled those 2 exploratory wells, one of which was a short horizontal. We completed that horizontal, made a natural gas discovery there. But ultimately, as I was just saying the prospect, we decided is not going to compete with our existing portfolio. So we won't be moving forward with that project. In general, we do feel encouraged with the international opportunities out there because we see really kind of a lack of exploration competition out there. And we see that many times, national oil companies or ministries, the owners of those lands have really started to realize that they can't rely on traditional conventional term contracts to be able to get some unconventional type prospects drilled. And so we're seeing a little bit more flexibility on the negotiation side, which gives us some encouragement.

And I'm going to hit on the shareholder returns too because obviously, you all are in a very enviable position. But Ezra and Tim, you guys talk about being opportunistic and countercyclical ways with your balance sheet then -- during the fourth quarter, I guess, post things given there was a little bit of a disconnect there. Your stock was a lot lower than it is today. Why not take that opportunity then to buy back stock? Can you -- so just trying to frame for us like when you think the right opportunities to buy back stock are.

Yes. In general, Scott, we didn't see that as one of the opportunities that we're looking for there in the fourth quarter. When we talk about the significant dislocation, we're talking about something more so than that. Like I said, we consider share repurchase in the same way that we do any investment decision. It's how does it create the most long-term shareholder value. And we're in a cyclical industry, and that's why we prefer to use it opportunistically with a significant opportunity. The challenge, of course, is we recognize that being in a position to execute during the market dislocation is a challenging thing to do. However, we feel with the strength of our balance sheet and the low cash operating cost that we have, we'll be well positioned when we see the opportunity.

Our next question today comes from Leo Mariani from KeyBanc. Please go ahead. The line is yours.

I wanted to see if there's any update on the PRB. Certainly noticed in the slide deck that activity there is going to be down a little bit in terms of a few less wells in '22 versus what you did in '21. So perhaps you could kind of speak to how well costs have trended and kind of where that opportunity is on your list amongst the different plays? Clearly, you described a significant increase in Delaware activity this year. So how does the PRB rank?

Leo, this is Jeff Leitzell. The PRB, we're really excited about where it's going. In 2021, we had a record year, both from a well performance and an economic standpoint. Last year, our team, they continue to really delineate our core areas. They completed about 50 wells and half of those exceeded our double premium threshold. So we're really encouraged by that. On top of that, we also brought on multiple record wells in the basin, both in the Niobrara and the Mowry formations, all doing this while reducing our cost year-over-year by about 10%. So the one thing that we really look at with the Powder River Basin is it's a little bit more geologically complex compared to our other basins. So it's really important that we operate at the right pace, and we don't outrun our learnings. So looking forward kind of to 2022, we plan on maintaining a similar amount of activity and as our team there really high grades our acreage, refines our well spacing and strategically build out our infrastructure, we really expect the Powder River Basin asset to be able to increase activity in 2023 and beyond.

And then if I can just take another crack at the kind of exploration. So I certainly noticed that you guys are spending about by numbers of right around $100 million more on some of these U.S. plays here in '22, and you clearly talked about drilling more wells. I guess a common question I hear from investors out there is it's been a number of years since EOG has kind of announced the strategy, and I guess we'd kind of get to see a new significant U.S. oil play for the company. I know these things are hard to predict, but if I had to just kind of look at a high-level time line. I mean, do you think that's likely in '22 or maybe '23? I mean anything you can kind of say from a high level to get people some assurance that maybe these are progressing?

Yes. Leo, what I'd say is it's just really hard to predict, and I'd hate to commit to something to lead you down the wrong path. I might point to historically, we did some early drilling in the Powder River Basin, and it was a number of years before we felt comfortable We gotten that to a point where we want to talk about it publicly in a big way. And then the same with Dorado. I know there was a lot of speculation as to our Austin Chalk exploration program for a number of years. And as you can see, we waited until we had some long-term production and felt confident as to what we had there before we started really talking about it publicly. The current exploration program was definitely slowed down, even maybe a little bit more than we anticipated during the pandemic. It was just a little more difficult even to get leasing done and things of that nature. As we talked about in 2021, the plays coming out of the pandemic had really started to move it kind of various paces or various rates. Some of the wells last year that we drilled were the initial wells in these plays. In other prospects, some of the wells, we're really testing a little more delineation, repeatability, more appraisal. Because again, like I said, almost more than an exploration program, what we're trying to find is not just oil. That's not necessarily the most difficult thing anymore. It's really, as you guys can appreciate, trying to find low-cost barrels, barrels that are additive to what not only we have already discovered but what the industry has really discovered, what the world wants is access to lower-cost barrels, and that's what we're searching for. And so it takes a little bit longer to be able to really get the appraisal on these and make sure that these opportunities are really going to be additive, again, to the quality of our inventory.

The next question today comes from Jeannie Wai from Barclays. Please go ahead. Your line is open.

Our first question is maybe just back to the double premium. You added 700 new net double premium locations in 2021. And were these additions spread out across your plays? Or are they concentrated in maybe one or two of them? And where do you see the most runway for future conversions?

Yes. Jeanine, thanks for the question. This is Ken. We added double premium locations over a number of our active premium plays, really in line with where we drilled our wells last year, mainly in the Permian and the Eagle Ford. And this is really just an example of our culture where we're working to get better, continuing to lower well costs while focusing on increasing the recovery is what leads to significant increases in returns and really allows us to convert wells to premium and double premium through time. And our goal is to always replace at least as many double premium locations as we drill every year.

Maybe our second question, maybe 1 for Tim or Ezra. In the past, I think if memory serves me correctly, I think you've commented that after you pay off the 2023 notes that you don't really have a desire to pay down any further debt. I just wanted to check in if that was still the thinking? And I think we're just really looking for a little bit more color on how you decided that $1 per share for the special this time around was the optimal level?

Yes. This is Tim. No, we have not announced any intention of paying off more bonds as they become due. We'll continue to evaluate that as we go forward, but we -- that did not figure into the dollar was a way of giving back meaningful amount of cash to the shareholders in this period. And as we said, that's a backward-looking thing, not a forward-looking thing.

Our final question today comes from Neil Mehta from Golman Sachs. Please go ahead. The line is yours.

I know EOG has developed some more internal macro forecasting capability. And I'd just be curious on your views on U.S. shale production in the United States. How are you guys thinking about it entry to exit U.S. oil growth? And talk about the moving pieces ranging from what you're seeing from your competitors in the private market to services constraints such as pressure pumping, your thoughts on U.S. growth would be valuable.

Yes. Neil, I'll add a bit of an overview, and then maybe I'll hand it off to Billy for some more details for you on the activity side. But in general, when we think about the growth forecasts that are out there and have been publicly discussed, we're probably a bit more on the lower end in general on the crude and condensate side. And the reason for that is I think you're seeing commitment from the North American E&P space to remain disciplined. And then you couple that with some of the inflationary and supply chain pressures. And we think the U.S. is definitely going to face some headwinds in growth on this year. And I think Billy can provide a bit more details on it.

Yes. Neil, this is Billy. I'm sure you've heard the same comments from many of our peers about the supply chain constraints in the industry is seeing across all the sectors, certainly on the drilling rig side, there's certainly most of the active super-spec rigs are being -- are deployed and active today. There's not a lot of new pieces of equipment that can come into the market. The same is true on the frac side of the business, most of the good equipment is already under employment today. And then bringing in new fleets, both on the drilling side and on the frac side, is challenged also from the standpoint of attracting labor to the market. So there's a lot of headwinds to try to -- for the industry to try to ramp up activity and grow production this year. So it will be a probably viewed as maybe a transition year also in that light. And hopefully, the industry can strengthen and get better on a go-forward basis. But this year is going to be a challenging year from that side.

And then the follow-up is around natural gas, both U.S. and global. A lot of moving pieces, obviously, right now from a geopolitical standpoint. But the most of the industry has been of a lower-for-longer U.S. natural gas view. Do you see that evolving as we have more LNG linkage into the global market? If you think about global gas, especially in light of your announcement with do you see a structural change in this market until Qatar supply comes on mid decade?

Yes. Neil, this is Ezra. In general, what I would say is the U.S. has discovered a very vast supply of natural gas, and it's important that we get that gas offshore and into the global market for some of the reasons that you talked about now, not only geopolitical, but just developing nations, so on and so forth. And that's one of the reasons where we're so glad to partner and continue to take out some of our LNG. For us, the way we think about the natural gas globally is really it's going to be a cost of supply. And we say that we want to be the low-cost producer, and that might sound like we're talking about oil dominantly, but that goes for gas as well. And it's one reason we're very excited about our Dorado prospect. We think it competes in North America is basically the lowest cost of supply, especially because of its geographic location, close to so many marketing centers, including the Gulf Coast. So we're very excited and very fortunate to have it. And I think the U.S. is going to continue to be, in the long term, a significant player in the global gas supply.

Thank you. This concludes today's Q&A session. So I'll now hand the call back to Mr. Yacob.

Yes. We want to thank everyone for participating on the call this morning, and we want to thank our shareholders for their support. As we said, EOG had an outstanding performance in 2021, and we're poised for an up great year in 2022. And it really comes down to our employees. Our employees are the keys to our success, and it's why I'm convinced are to being one of the lowest cost, highest return and lowest emissions energy suppliers that can play a significant role in the long-term future of energy. Thank you.

This concludes today's call. You may now disconnect your lines.