EOG Resources, Inc.

Good day, everyone, and welcome to EOG Resources' first quarter 2021 earnings 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. Thank you.

Good morning, and thanks for joining us. We hope everyone has seen the press release announcing first quarter 2021 earnings and operational results. This conference call includes forward-looking statements. The risks associated with forward-looking statements have been outlined in the earnings release and EOG's SEC filings, and we incorporate those by reference for this call. This conference call also contains certain non-GAAP financial measures. Definitions as well as reconciliation schedules for these non-GAAP measures to comparable GAAP measures can be found on our website at www.eogresources.com. Some of the reserve estimates on this conference call or in the accompanying investor presentation slides may include estimated potential reserves and estimated resource potential not necessarily calculated in accordance with the SEC's reserve reporting guidelines. We incorporate by reference the cautionary note to U.S. investors that appears at the bottom of our earnings release issued yesterday. Participating on the call this morning are Bill Thomas, Chairman and CEO, Billy Helms, Chief Operating Officer, Ezra Jacob, President, Ken Bedecker, EVP Exploration and Production, Lance Turveen, Senior VP Marketing, and David Streit, VP Investor and Public Relations. Here's Bill Thomas.

Thanks, Tim, and good morning, everyone. EOG is delivering on our pre-cash flow priorities and our strategy to maximize long-term shareholder value. Yesterday, we declared a $1 per share special dividend to demonstrate our commitment to returning cash to shareholders. Combined with the regular dividend, we expect to return $1.5 billion to our shareholders through dividends in 2021. Double premium well productivity and cost reductions are substantially improving our returns and increasing our ability to generate significant free cash flow. In order to maximize long-term shareholder value, we will remain flexible as we carry out our free cash flow priorities in the future. By doubling our reinvestment standard, the future potential of our earnings and cash flow performance are the best they've ever been. This quarter, we generated a quarterly record $1.1 billion of free cash flow and earned $1.62 per share of adjusted net income, the second highest quarterly earnings in company history. In addition, our balance sheet is in superior shape, with a peer-leading low debt-to-cap ratio. Next, Ezra will review our capital allocation strategy in more detail. Billy will go over our operational performance, and Tim will cover our financial performance before I make a few closing remarks. Now, here's Ezra.

Thanks, Bill. Yesterday's dividend announcement is just the latest in a long line of achievements that demonstrate the value of EOG's fundamental strategy of returns-driven capital allocation, including the impact of permanently raising our investment return hurdle rate for the second time in five years. In 2016, during the last downturn, we established our premium investment strategy, which requires a 30% direct after-tax rate of return at $40 oil and $2.50 natural gas. The premium investment strategy drove a step change in our capital efficiency and resulting financial performance. It is the reason we entered 2020 in a position of operational and financial strength, which enabled us to generate positive adjusted net income and free cash flow in a year of unprecedented oil volatility and prices that average just $39. This year, we increased the return hurdle once again, doubling it to 60% at $40 oil and $2.50 natural gas. Sustainable improvements in our inventory of drilling locations and continued progress and exploration have paved the transition to double premium. The data driving our confidence to make this move is illustrated on slide six of our investor presentation, which details the return profile of every drilling location. Half our current inventory earns at least two times the premium return hurdle rate we established back in 2016. 5,700 double premium locations is more than 10 years worth of inventory at our current pace of drilling and is more than we had when we made the transition to premium five years ago. Just like we did with our premium inventory, we are confident we can replace our double premium locations faster than we drill them through line of sight into additional cost reductions that will increase the returns of existing inventory and through exploration. A number of innovations, which Billy will discuss in a moment, are being piloted across our operating areas and will sustainably drive down both well costs and operating costs as we implement them throughout the company. Our exploration program is focused exclusively on prospects that will improve on that 60% median return. In fact, our anticipated return on the current slate of new exploration plays is more than 80%. To see the impact of our premium returns-focused capital allocation strategy, a closer look at our corporate financial performance is required. As we replace our production base by drilling locations with higher well-level returns, the price required to earn 10% return on capital employed continues to fall. Prior to establishing premium, EOG required oil prices upwards of $80 to earn a 10% ROCE. As the premium strategy matured, the oil price needed to earn 10% ROCE came down and averaged just $58 the last four years. This trend is illustrated on slide 9 of our investor presentation. For 2021, that price is just $50, and we're not stopping there. We expect it will continue to fall as our well-level returns improve. The impact of reinvesting at higher returns is also showing up in our free cash flow performance. We more than doubled the dividend over the last four years and improved our balance sheet, reducing net debt by nearly $3 billion. As a result, net debt to total capital at the end of last year was just 11%. But our future financial performance potential is the real prize. Our first quarter results are a preview of what we are aiming for. Over the coming years, we expect reinvesting in our current inventory of high-return wells will continue to lower the corporate decline rate and compound the value of our low-cost operating structure. The result leads to higher margins and generates even more free cash flow, providing us tremendous opportunity to create long-term shareholder value. We believe when we look back in a few years, it will be viewed as the catalyst for another step change improvement in EOG's financial performance. Our fundamental strategy of returns-driven capital allocation remains consistent, and consistency is key. Prioritizing reinvestment in high-return projects is the driver behind the steady improvements we've made year after year. As a result, we are now in a position to follow through on our commitment to return additional free cash flow to shareholders. Looking ahead, you can expect our priorities to remain consistent. Investing in high returns, generating significant free cash flow to support a sustainable and growing dividend while maintaining a strong balance sheet, followed by opportunistic return of additional free cash flow to investors and bolt-on acquisitions. Now here's Billy. Thanks, Ezra.

The first quarter of the year was about execution. We exceeded our oil target, producing more than the high end of our guidance range because wells that were offline due to the winter storm Uri recovered a bit faster than expected. As a result, our first quarter daily production declined just 3% compared to the fourth quarter last year. Our capital for the quarter came in under our forecasted target by 6%, mainly due to improvements in well cost across the company. The savings realized during the first quarter are in addition to the tremendous 15% reduction last year. EOG is on track to reduce well cost another 5% this year, despite some potential inflationary pressure as industry activity resumes. Similar to previous quarters, these results are driven through innovation and efficiency gains in each phase of our operation. A closer look at our operations will help explain why we are confident we can once again lower well cost. Our drilling teams are consistently achieving targeted depths faster with lower cost. The constant focus on daily performance and reliability of the tools and technical procedures is creating this continual drive towards lower cost. Some of the benefits this year stem from larger groups of wells per pad simply requiring less rig move cost per well and increasing efficiencies like offline cementing. The larger well pads also complement our completion operations through the increased ability to utilize a technique we call SuperZipper. We began our initial experiments with this technique back in 2019, and it has since advanced to consistently deliver the expected well results at lower cost. We have also learned that SuperZipper is particularly well suited to optimize the efficiencies of our five electric frag fleets. However, conventional spreads gain efficiencies as well. This practice involves using a single spread of pressure pumping equipment to complete four or more wells on a single pad. We split the equipment's capacity in half, simultaneously pumping on two wells while conducting wireline operations on the remaining wells. We piloted and perfected a super zipper logistics in our Eagleford play, and the collaboration between operating areas has accelerated its adoption throughout the company. And, in cases where a minimum of four wells cannot be physically located on a single pad, the engineering teams are working to develop new techniques where we can still utilize this improved completion practice. Completion costs are also benefiting from reduced sand and water costs through our integrated self-sourcing efforts. The savings we realized by installing water reuse pipelines and facilities saves about 7% of well cost compared to third party sourcing and disposal. Longer term, we expect water reuse and disposal infrastructure will continue to lower lease operating expense in each area as well. Lease operating expense has also benefited from lessons learned through the pandemic this last year. The number of wells one lease operator can maintain has increased by as much as 80% by optimizing the use of innovative software designed and built by EOG. The software prioritized lease operator activity throughout the day using our mobile and real-time software infrastructure. Our experience last year inspired a number of new ideas to further high-grade a lease operator's work activity throughout the day, which we believe may continue to expand productivity in day-to-day field operations. Slide 35 of our investor presentation illustrates the consistent progress we have made year after year on productivity, all powered by innovative ideas generated bottom-up by employees. Each of our active operating areas functions as an individual incubator to test out new ideas, many of which are a homegrown innovation from EOG employees. and roll out company-wide if successful. That's one of the primary reasons our well cost improvements every year are never one silver bullet, but a list of small to medium-sized individual improvements across all elements of total well cost that result in sustainable cost reduction. As a result of the innovation spreading throughout the company to reduce capital and operating costs, I have strong confidence that the cost structure and capital efficiency of the company will continue to improve.

Here's Tim to review our financial position. Thanks, Billy. Yesterday's special dividend announcement marks another milestone in the growth of EOG's profitability and cash flow. We achieved this milestone through the disciplined execution of consistent, long-term, return-focused strategy for capital allocation supported by a strong balance sheet. Over time, this strategy has produced increasing amounts of free cash flow, The top priorities for the allocation of that free cash flow remain sustainable dividend growth and debt reduction. The shift to premium in 2016 drove a significant improvement in returns, profit margins, and cost, enabling the significant increase in the dividend over the last four years. Since 2017, the dividend has grown from $0.67 per share to $1.65 per share, now an annual commitment of almost $1 billion. Going forward, our goal is to continue growing the regular dividend. We have never cut or suspended the dividend, and we remain committed to its sustainability. With the shift to double premium, we're now focused on making another step change improvement, and the results of those efforts will guide future common dividend increases and the potential for special dividends. Since the shift to premium, we have also retired bond maturities totaling about $2 billion. with plans to retire another $1.25 billion in 2023 when the bond matures. Net debt to total capitalization was 8% at the end of the first quarter. A strong balance sheet with low debt has been at the heart of EOG's strategy throughout our existence. It's not just conservatism. It's about creating a strategic advantage. Our superior balance sheet enables us to acquire high return assets at bottom of cycle prices. whether exploration acreage like the Eagleford or for the new plays we're working on today. Both acquisitions are companies like the Lake Yates acquisition five years ago. A strong balance sheet also gives us the financial strength to be a partner of choice in our operations, whether it is with marketing or export agreements, service providers, or even other companies in other countries unlocking new plays. A strong balance sheet extends to ensuring ample liquidity which we have also secured, with no near-term debt maturities, $3.4 billion of cash on hand, and a $2 billion unsecured line of credit. Now, EOG is positioned to address other free cash flow priorities by returning additional cash to shareholders. The $1 per share special dividend follows through on these consistent long-held priorities. At $600 million, the special dividend is a meaningful amount while also aligning with our other priorities. After paying the special dividend, we will have $2.8 billion of cash on hand, a full $800 million above our minimum cash target. This is a healthy down payment on the $1.25 billion bond maturing in two years. Going forward, our free cash flow priorities remain unchanged. We will continue to monitor the cash position of the company, oil and gas prices, and of course our own financial performance. As excess cash becomes available in the future, we will evaluate further special dividends or at the right time, opportunistic share repurchases or low-cost bolt-on property acquisitions. I think it goes without saying you should expect us to avoid expensive corporate M&A. You can count on EOG to continue following our consistent strategy to maximize long-term shareholder value. Now here's Bill to wrap up.

Thanks, Tim. In conclusion, I would like to note the following important takeaways. First, true to the EOG culture, our employees have fully embraced doubling our investment hurdle rate. As we drill more double premium wells, we expect our performance will continue to improve. Our decline rate will flatten, our breakeven oil price will decline, our margins will expand, and the potential for free cash flow will increase substantially. Second, while our new double premium hurdle rate alone will drive significant improvement, it represents just one source. We never quit coming up with new ways to increase productivity and lower costs. Innovative new ideas and improved technology are developing throughout the company at a rapid pace and will continue to result in even higher returns in the future. And finally, our special dividend this quarter, we are demonstrating our commitment to generating significant free cash flow and using that free cash to improve total shareholder returns. We are more excited than ever about the future of EOG and our ability to deliver and maximize long-term shareholder value. Thanks for listening, and now we'll go to Q&A.

Thank you. The question and answer session will be conducted electronically. If you would like to ask a question, please do so by pressing the star key followed by the digit 1 on your touchtone telephone. If you are using a speakerphone, please make sure your mute function is turned off to allow your signal to reach our equipment. Questions are limited to one question and one follow-up question. We will take as many questions as time permits. Once again, please press star then 1 on your touchtone telephone to ask a question. If you find that your question has been answered, you may remove yourself by pressing the star key followed by the number 2. We'll pause for just a moment to give everyone an opportunity to signal for questions. And the first question comes from Scott Gruber of Citigroup. Please go ahead.

Yes, good morning. Hello, Scott. So the most common question we've received, I know you touched on it a bit in the prepared remarks, but just the The framework that you guys used to determine that the $1 special dividend was the right amount now is the right time. Can you just elaborate on that a little bit more around the framework and the timing? Obviously, folks are trying to get a sense of whether the special dividend can repeat in the future.

Yes, Scott. Certainly, we're demonstrating our commitment to our shareholders by returning a significant amount of cash back to them. And the $1 per share, I think, is a very significant number and large enough to be very meaningful. And I'm going to ask Tim to kind of go through some of the numbers to give you a little bit of the background on the reason that we picked this number. Thanks, Bill.

So, Going back to our priorities over time, it's consistent with our priorities. If you look back, our regular dividend has increased 146% since 2017. That's one of our highest priorities. We reduced that by $2.1 billion. So that set us up to be in a position to now return more cash to the shareholders. When we looked at our cash position, we were sitting at $3.4 billion of cash. So returning $600 million at this point in time, as Bill pointed out, is a significant amount, and it follows through on our long-held plan to return cash to the shareholders. So it's simply following through on what we've been committed to for a long time.

I want to add, Scott, going forward, our plans, Pre-cash flow priorities and framework haven't changed, and so you have to put the special dividend in context with our total framework. And just a reminder, we've already said this, but our first priority is sustainable dividend growth. We believe that regular dividend is the absolute best way to give cash back to shareholders, and we certainly are working on that and have got a great history of doing that. And then the next one is debt reduction, and we've got a little work left to do with that, as Tim noted in his opening remarks. Our next options are the special dividend, and certainly in favorable times like we have right now, those are the things that we are doing. And then we'll also, we want to keep in mind, you know, the potential for opportunistic share repurchases in downturns, counter-cyclic opportunities in share repurchases. And then after that, you know, we also... want to be able to consider high-return bolt-on acquisitions. And these are acquisitions that go in our best operating areas, obviously where we've got a lot of synergy and a lot of ability to move quickly and drill wells. And some of them could be in our new exploration place where we can capture a very high potential acreage at very low costs. And so we'll just continue to evaluate all these options and work with this framework and we'll evaluate the best use of cash on a quarter-to-quarter basis. We're in a dynamic business environment all the time, so it's important to have the flexibility to use the cash in a way that creates the most shareholder value.

Got it. And then my follow-up relates to the growth strategy in 22 and beyond. If the oil markets have healed next year, and you guys have been very explicit around the factors you're looking at, And you laid out the 8% to 10% growth case on your last call. But there seems to be some discussion now around the potential for a middle ground, if you will, maybe a growth case below that 8% to 10%. So I just wanted to hear your latest thoughts around 2022. If the oil markets have healed and it's time to grow again, what is the right growth cadence there? what factors are you looking at to determine that rate of growth if the markets have healed? You know, is there a middle ground, you know, somewhere between zero and eight to 10% or is it just, you know, if it's time to grow, we're going to grow at eight to 10%.

Yeah. Thanks. Thanks Scott for that question. We want to make sure we're really clear on that. And I think we have, you know, we're, we're not going to grow until, you know, demand, um, is recovered to pre-COVID levels, which it's on the way to do that. I think everybody can see that. And we want to make sure that, obviously, world inventories, U.S. inventories are below the five-year average. And then we're looking for spare capacity to be certainly a lot lower than it is right now. And that just means, you know, not a lot of oil shut in to match supply and demand. And every year... The market factors, you know, that year going into that year will determine our plans. And so we want to be flexible, and we want to be able to, and we will, modify our growth plans to fit those market conditions. If we need to grow at a lower rate or no growth at all, like we're doing this year, you know, whatever that right growth plan is, whatever fits the market conditions, that's what we want to do. Above all, everything else, we are committed to staying very disciplined and not forcing oil into a market that's not ready.

Got it. Thank you. Appreciate the call.

The next question comes from Arun Jayarma of J.P. Morgan. Please go ahead.

Yeah, I guess my first question is kind of to dovetail on the special dividend talk. Bill, this year you've guided to $3.4 billion in free cash flow, $1.5 billion for dividends, another $750 for debt you've already paid down. So that leaves a little bit more than $1.1 billion of free cash flow, and I know you're above your minimal cash target. So I guess the question is how are you – gauging, you know, the market for bolt-ons versus, you know, potentially if the oil price, you know, holds up here in terms of looking at, you know, more cash return this year.

Yeah, thanks, Saroon. You know, we take the – we evaluate, you know, where we are every quarter. You know, I can't give you any specific on anything here. But we evaluate where we are every quarter, and we're constantly looking at bolt-on potential and evaluating that. So we want to make sure we leave room to fully consider that, something that would make a very significant difference in the future of the company, upgrade our high-quality premium, double premium inventory. We want to do that. You know, we're very fortunate. We've got a lot of cash, and we've got a lot of, hopefully, we believe a lot of cash coming. So that's a lot of great opportunities for us to consider, you know, additional special dividends, both on acquisitions, et cetera. And then we keep in mind, you know, as Tim talked about, we want to keep in mind our debt reduction targets in a year. And then, excuse me, in 2023. and also be able to continue to think about growing our regular dividend. So we'll just keep all those in the proper framework, and you just need to know that we're committed to doing the right thing at the right time for the shareholders to maximize total shareholder value.

Great. And my follow-up, Bill, you cited this as being the company's best free cash flow quarter. in history. But I wanted to see if you could provide a little bit more detail on how the unique pricing conditions for natural gas, given Winter Storm Uri, some of your leverage to JKM, how that contributed to the free cash flow. How would you call that out? I know there were some incremental costs, but what was the puts and take on the gas price this quarter?

I'm going to ask Tim to give some details on that, but just to Before I turn it over to Tim, everybody needs to know the special dividend has nothing to do with the storm and the natural gas process. So, Tim, you want to give some detail?

Sure. When you boil everything down, the effects of URI was about $40 million to cash flow and net income in the quarter. Obviously, there are big components in there, but that's the bottom line. It was very immaterial to our cash flow, our net income.

Okay, great. Thanks a lot.

The next question comes from Scott Hanold of RBC Capital Markets. Please go ahead.

Thanks. First and foremost, you know, I appreciate your very direct commentary on your desire not to grow and, you know, what the plan is. So hopefully that does clear the air a bit. You know, what I'm wondering is strategically if we do stay in sort of the current environment, whether it's 22 or even beyond, you all do build a lot of free cash flow. I mean, we're talking, what, something around $3 billion even after your base dividend annually. Do you all see if there is a benefit into setting up a more predictable cash return to shareholders like some of your other peers did? Do you think there's a benefit to that predictability, or would you rather see that more opportunistic?

Yeah, Scott, you know, we're always in a very dynamic business environment, so it's important, you know, we believe, to have the flexibility to use the cash in a way that creates the most shareholder value. You know, one of the reasons we don't, the biggest reason we don't want to get into a strict formula, because we don't want to be put into position to where we're growing oil, say, at 5%, when the market clearly does not need more oil. So we want to be in a position to where we can do the right thing at the right time and to maximize the use of the cash in our plan to maximize shareholder value.

Got it. Thank you for that. And my next question, maybe this one's for Ezra. you know, you all talked about, you know, shifting the double premium that's generated, you know, significant increases to EURs. I think page eight shows just a massive uptick. Do you all have any color on, you know, how much of that is organic versus mixed shift? I would assume the shift to relatively more Permian has, you know, relative to say Eagleford has biased that upward, but Do you have a sense on, you know, how much is mix shift versus organic?

Yeah, Scott, thanks for the question. This is Ezra. Yeah, definitely in the Permian we have a higher percentage of those 5,700 double premium locations are located in the Permian. But part of that is simply just because we have so many targets captured there in the Delaware Basin. What I would say is we have a fairly wide variety and fairly distributed variety of double premium wells across our entire portfolio, including the Eagleford, the recently announced Austin Shock Dorado Play, and the Powder River Basin as well.

The next question comes from Doug Legate of Bank of America. Please go ahead.

Thank you. Good morning, everyone. I apologize. I was just taking you off my headset. Bill or Ezra, I wonder if I could press on Scott's point. I'm afraid I'm not quite where Scott is in thinking this draws a line under the growth story. So my question is real simple. You currently have one of the lowest free cash flow yields in the sector, arguably a reflection of your share price. But my point is that everyone's got the capacity to spend more money What happens to your 10% return at $50 oil if the whole industry follows your lead and goes back to a 10% growth rate?

Yeah, Doug, I want to make it really clear. We're not stuck on 10% growth rate or 8% growth rate. We are totally focused on making sure we do the right thing at the right time. guide how much we're going to grow, it's the market fundamentals. And so we're really focused on that. We've laid out, I think, a strong set of fundamentals that we're focused on. And we will adjust our plan each year, which means our growth plan each year, to those market fundamentals. And it may be certainly next year that we don't grow at all, or we may grow at 4% or 5%. We'll just have to see what the market fundamentals show.

That's actually a great answer, Bill. It's not set in stone. It's kind of what I was really trying to get to. My follow-up is Ezra, very quickly. Ten years of inventory, double premium at the current pace. If you do choose to go back to growth, one assumes that ten years shrinks some. So can you talk about the sustainability and how that plays into, again, how you think about that activity level? I'll leave it there. Thanks.

Yes, Doug, that's a good question. Similarly, as we've done over the past few years, you know, we're consistently focused on getting better year after year. And so by driving down well costs through sustainable well cost reductions, some of which Billy spoke to in the opening remarks, but also through applying technology and innovations to increase the well productivity gains, we're able to convert some of our existing inventory every year into that double premium metric that In addition to that, we have two other avenues. The first which Bill has touched on is bolt-on acreage acquisition opportunities in areas of pre-existing development, but then also our exploration effort. And as I talked about in the opening comments, our exploration effort is really focused on, again, making another step change to our current inventory. It's focused on adding low decline, high impact plays that really increase the overall return profile of the company. And again, regardless of any growth rate, when you're reinvesting, In higher return opportunities and adding lower cost reserves to your company, you're really, you know, driving down the cost base of the company year after year. And that's essentially what translates into our corporate financials and allows us to lower that price required for a double-digit ROCE every year.

The next question comes from Neil Dingman of Truist Securities. Please go ahead.

Morning, all. Guys, my first question is around how you look at your reinvestment rate. I'm just wondering, number one, could you talk about at sort of current strip how you see the reinvestment? And, you know, again, let's assume another $5 or so higher. What would that do to that?

Yeah, Neil, thanks for the question. We're going to ask Billy to comment on that.

Yeah, thanks, Neil. I think, you know, for the reinvestment rate, we're always – looking at, you know, as Bill mentioned earlier, what's the market look like and what's the need for oil. And we're certainly not going to grow into a market that doesn't need the oil, as he pointed out. I was trying to make sure to reemphasize that point. And then going forward, each year we'll do the same thing we always do. We kind of see where the market is and what the prices are and what our opportunities are to develop our assets. And we balance that against the cash needs of the company. So it's not really a straight formula. It's more about where the market is at that current time.

I'm glad to hear that. I wish more others would say the same. And then just to follow up, could you talk about, you know, I would call this question more on sort of your regional allocation process. I know, Bill, you talked about sort of the the new hurdles, uh, the premium, you know, locations, but I'm just wondering how, how does that factor in when, you know, you've got some exciting, you know, that not quite as developed areas like in the PRB, but I think have high potential. But if you're just strictly looking at maybe what they produce immediately might not compete. So I'm just wondering how do you factor in some of those high potential wells, uh, with this plant?

Yeah, Neil, this is Billy again. Um, let me take a stab at that. Um, So as we look at all of our assets, that's the beauty of having a decentralized culture where we are focused on multiple plays across our portfolio. You have plays that are in different phases of their life cycle, as you might think about it. As you just said, like the Eagleford is a more mature play. It's had a growth for about 10 years. It's further down the maturity window than, say, the Delaware Basin. And then the Powder River Basin is certainly an early maturing or early growth phase play. So each one of those, we certainly go in with the idea of delineating the play first, putting in the infrastructure to drive down our cost over time and maximize returns. So each one of those have a different life cycle that commands a different amount of investment. And overall, though, the company is able to maintain a very steady pace of activity and future value creation through the way we operate the company.

The next question is from Leo Mariani of KeyBank. Please go ahead.

I'm spending here. Certainly noticing that just based on your guidance, your CapEx is picking up here in the second quarter. Just wondered what was sort of driving that, and I wasn't sure kind of, you know, what was kind of causing that.

Yeah, Leo, this is Billy. So the guidance on the CapEx, it's up a little bit in the second quarter relative to the first quarter. It's simply the timing of when wells are available to be completed. So we'll have a little bit more completion activity in the second quarter than we did in the first quarter. That simply is. I think in general we'll have about 52% of our capex spent in the first half, the remaining to be spent more ratably through the rest of the year. And the volumes will be really pretty much keeping with that 440,000 barrels a day per quarter average the rest of the year. So we'll be maintaining 440,000 barrels a day each quarter going forward.

Okay, that's helpful for sure. And just wanted to ask on the exploration plays, if I'm not wrong, I think you guys are certainly devoting more capital there, particularly to the drill bit in 2021 here. I just wanted to confirm, are you guys kind of drilling out multiple plays at this point? I think you did a little bit of that in the last couple of years as well. And as a result, you know, maybe just can you kind of speak to, you know, high level what your confidence is and being able to maybe, you know, prove some of these up in the next year?

Yes, Leo. This is Ezra. Appreciate the question. Yeah, on our exploration plays, you're right. We've allocated about $300 million to the exploration effort this year. Over the last few years, we've done a little bit of drilling. It was dominantly kind of leasing, putting some of the acreage together. And then, of course, there was a pullback here in 2020 due to the reduction in capital allocation associated with downturn in prices and COVID. But this year, we are back to drilling multiple prospects. We're at a point where the prospects have started to move at different phases, I would say. We're drilling exploration wells across some of the prospects, across others. We're into more of what I'd call appraisal wells, and we're feeling very confident with where we're at, the results that we're seeing, and we hope to be able to provide some results on that soon.

The next question comes from Janine Way of Barclays. Please go ahead.

Hi. Good morning, everyone. Thanks for taking our questions. Maybe a question for Ezra following up on the exploration. You're in Oman now, and I believe we saw last month that you paid a nominal amount for an interest in the Beehive Oil Prospect Offshore Australia. So can you talk about what attracted you to Australia, and do you still have interest in other international plates?

Yes, Janine. That's a great question. This is Ezra. Yeah, the opportunity there in Australia, as you mentioned, it's on the northwest shelf. Obviously, everyone knows a very prolific hydrocarbon region. It's a shallow water opportunity that we've stepped into there, as you mentioned, for a very low upfront cost. It's exposing us to a prospect that we think has The opportunity, the potential to be impactful to our company, we're forecasting it as the potential to really compete with our domestic returns. And the opportunity that we have here in Australia is really an outgrowth of our experience in Trinidad. where for nearly 20 years we've been operating in the shallow waters offshore of Trinidad. And really, this is a geologic province, a type of play where industry has really moved away from. And so we found ourselves as kind of a niche operator, and we've developed not only operational procedures, but also some geologic techniques where we think we can come into some of these shallow water prospects and make very, very good returns. The attractive thing about Australia, again, is not only does it fit into our experience level from operations and a technical perspective, but it has many off-take and oil field service availability there. And, of course, the low cost of entry to, you know, an exciting amount of upside in the prospect.

Very interesting. We'll be looking forward to that. My second question, and I apologize in advance for paraphrasing, beating the horse again on this, but on the special dividend, the perception in the market is simply that cash returns aren't consistent or formulaic. You can't capitalize on the valuations. You don't get credit for it, et cetera. With that in mind, you mentioned that you evaluate the health of the business every quarter, probably more frequently than that. And specifically, when it comes to the special dividend, can you just clarify, is it really a matter of just holding $2 billion in minimum operating cash plus $800 million to $1.25 billion for the 2023 maturity, and then everything else kind of gets paid out in due time, and it kind of needs to be meaningful. I know you also mentioned a couple of times that having optionality for high return full-times is also one of the priorities. So if you have any kind of commentary on what a comfortable placeholder for that would be, that would be really helpful. Thank you.

Yeah, Janine, you know, Tim's given, you know, I think some answers for some of those on there. Yeah, we want to keep Apple cash on the table. on the balance sheet to run the business, and that's around $2 billion. And then, you know, we have set aside or are looking at plans for reducing the $1.25 billion bond in 2023. So that's all fits in, and that's part of our, you know, evaluation of how we use the cash and when we use the cash. But really, the special dividend just fits into, you know, the framework that we've already laid out in our commitment to giving back cash to shareholders. So, you know, we will look at our cash position, look at a bolt on potential opportunities. They can truly be any size, you know, from a very small, we've done them in the past, you know, 20, $30 million deal, but they could certainly be bigger than that too. So, We'll take all that and work it into our framework and evaluate where the company is and the outlook for the business. Our goal is to continue to return cash to shareholders through that framework.

The next question comes from Charles Meade of Johnson Rice. Please go ahead.

Good morning, Bill, to you and your whole team there. I really just have one question, and it goes back to some of your prepared comments, Bill, and more specifically share repurchases. Yeah, I recognize that that hasn't been your MO in the past, and they kind of have a bad reputation maybe because usually share repurchases wind up being pro-cyclical. And the way you talked about it, you said – For you, you would look at it in an opportunistic way is the word I remember, and you said in a downturn. And I guess my question is it's easy to see a downturn in retrospect, right? Six months ago, you guys had a three-handle on your stock, but it's hard to recognize when you're in it. So is there any guideposts that you can share about how you would recognize when you're in one of those downturns? downturn since it's time to be opportunistic, or is it just one of those things you know when you see it?

Yeah, Charles, I think, you know, it goes right along with the supply, demand, and market fundamentals analysis that we do. You know, we've gotten more sophisticated. We've got a very sophisticated model now developed through our information technology, and we're gaining a lot of confidence in it. on being able to kind of be on top of the oil market and where it's headed. And certainly the oil price, that's the biggest indicator. But we, I think we'll be able to determine, you know, when's the right time, when's the opportunistic, counter-cyclic time to maybe consider share buybacks. And of course now, you know, we have... A lot of cash on the balance sheet, and we want to continue to watch that and keep that. We'll have an opportunity when we do have a downturn to have cash to do that if that happens. Thank you, Bill.

The next question comes from Neil Metza of Goldman Sachs. Please go ahead.

Good morning, team, and congrats on a good quarter here. The first question is, Bill, any updates on permitting on federal lands and how that process has been to apply for new permits? And in general, in your conversations with Washington, does it seem like some of the risks around the federal lands exposure in the Delaware has diminished?

Yeah, Neil, this is Billy Helms. So on the permits, the federal permits, certainly we were very active in obtaining permits prior to the administration change just to protect our activity levels. Since that moratorium has been lifted, we are receiving a steady stream of permits. The permit stream is coming very well. receiving permits in all of our areas, too. So I think the working relationships we've been able to maintain with the regulators and working through the process with them has benefited us real well. So we're not really seeing any restrictions there. And I think the Biden administration clearly has said that activity, he wants to maintain activity on uh, valid leases. Uh, so we're very comforted by the fact that, uh, we'll be able to continue that.

That's great guys. And the followup is just on the macro. Uh, you guys talked a little bit about the tools that you have to evaluate, uh, direction of oil price and the way things are trending. Be curious if you could unpack what you're seeing real time, um, and how you're thinking about, um, the commodity price moving from here for both for oil and for natural gas?

Yeah, Neil, on oil, you know, as we already talked about, the fundamentals are definitely improving. You know, it's been a little bouncy on the COVID recovery and oil demand, but we're seeing very, very steady improvements. I think we're up to maybe 95 million barrels a day. Demand right now, we think, you know, maybe by the end of the year that will get to pre-COVID levels of somewhere around 100 million barrels a day. We'll just have to watch it and see. The inventories are dropping. We think, you know, there will be fairly consistent draws on inventory from here on out, especially during the summer pickup activity and, you know, So that's all looking really good. And then, you know, the spare capacity, you know, is going fine. It's been extended and drawn out a little bit further than what it started out to be at the beginning of the year. But, you know, we believe, again, as demand picks up, that that spare capacity will be put back online, you know. We don't want to give you, you know, the data when everything's okay. We'll just have to watch and see it. But certainly everything is going in the right direction. And I think the market, you know, as oil prices have responded to that, I think it's that what we're saying and seeing is not different than what the consensus view is. On natural gas, you know, we're mildly bullish. Inventories are low and supply is less and demand is higher. this year than supply. So we're going to be entering the summer and particularly the fall of the year with pretty low inventories. So obviously it always depends on the weather on gas. And so we'll just have to see how all that turns out. But we're optimistic on gas also.

The next question comes from Michael Ciala of Stiefel. Please go ahead.

Yeah, good morning, everybody. You've highlighted for quite a long time your ESG sustainability ambitions. I just want to see where you stand on the government putting a price on carbon or carbon tax, and do you see any economic opportunities in the energy transition for EOG?

Yeah, Michael, I'm going to ask Ken. to talk on that. Before we start, the carbon tax or issues like that, we're going to leave those up to the legislatures and not come out with our opinions on that. We'll work with whatever transpires on that. Ken, you want to talk about other opportunities?

We really have no interest in a lower return business that this might lead to, but we've really made excellent progress in and reducing our emissions over the last four years. And you can see that with our intensity rates coming down as indicated in the attached slides that we've got on the presentation there. We're focused on reducing our own emissions with projects that have competitive returns before we consider a second phase of applying technology such as carbon capture to reduce our emissions. And we do believe that we can use, you know, 1% to 2% of our capital budget every year to make a substantial progress towards our goals of no routine flaring by 2025 that's been endorsed by the World Bank and our ambition of scope 1 and 2 net zero by 2040. Okay, thank you.

Billy, you mentioned some of the things you're doing to lower well costs, the larger pads and the super zippers. Some of your competitors have talked about three-mile laterals in the Permian. I think you guys have done some two-mile-plus laterals in the Eagleford, but do you see a trend toward three-mile laterals, particularly in the Permian, or if not, what are the issues that would prevent that?

Yeah, thanks, Michael. Yeah, thanks, Michael. So on the On the three-mile laterals you ride, we've done several, I'd say, between two-and-a-half and three-mile laterals in multiple plays where it makes sense. And we do them probably more predominantly in the Eagleford. And then we've had some in the Bakken and also in the DJ. But there are unique circumstances that allow that to happen for us, and they're more – driven by geology in that particular area, but also the access issues on the surface. I think just as a general rule, I'm not sure that it always makes sense to go through to a three-mile lateral. I think you have to take into account the efficiencies of being able to complete that last mile of lateral economically compared to a two-mile lateral, those kind of things. And a lot of it does depend on the geology. And as you know, we spend a lot of detailed time working through of the geology and how to best approach every single well location we have. There are some limitations on where you can do that effectively, so it's not a broad brush approach.

The next question comes from Vincent Lozaglio of Mizuho. Please go ahead.

Hey, guys. Thanks for having me on. I wanted to ask on the double premium locations, you might have touched on it last quarter, but if there's anything unique to the geology across these plays that lends itself to higher productivity, but also the lower decline described in slide eight. And, you know, if so, how that might affect your pursuit of new opportunities that are double premium, why you guys are differentiated in that pursuit and also in the development of those opportunities.

Yes, Vin, this is Ezra Jacob. That's a great question. And, you know, what we're highlighting there in the slide deck, it really comes down to what you touched on with the unique geology. These are the double premium plays are usually in areas where we've really refined our target down to get, in our existing portfolio, down to get rock quality that is higher, better permeability. And really the big step change is as we look forward into the exploration prospects. As we've talked about before, We're looking for new plays that historically haven't really been drilled routinely with horizontals. We're looking for a higher quality of rock so we can apply the horizontal drilling and completions technology to. And really, it's the higher permeability, higher porosity that lends itself to the shallower declines. And we think that this is not only going to be a step change for our performance as a But really, potentially, those are going to be the new reservoirs that industry eventually is looking at to apply horizontal drilling to in the future.

Perfect. Thanks. And maybe second, any additional color that you can maybe give on unconventional EOR, just where it stands in the Eagleford right now, thoughts on applicability across other plays, and then maybe how that could improve your environmental footprint going forward. Thanks.

Yeah, this is Ken. As far as EOR goes in the Eagleford right now, we've hydrated our EOR process, and we have some of our units that are in blowdown and other units that we're continuing to inject into. EOR is much more challenged in a higher gas price environment with our double premium returns, so we are evaluating it for other areas based on that across the company.

The next question comes from Nitinan Kumar of Wells Fargo. Please go ahead.

Hi, good morning, gentlemen, and first of all, congratulations. The market is definitely receiving the special dividend very well. My question is perhaps a little different from some of the other ones I've been asked. Over time, I was looking at slide nine, you've migrated to this double premium strategy. With the macro environment as favorable as it is, What happens to the single premium or the lower half of your core inventory here? As I mentioned, the expiration phase can have returns as high as 80%. So just wondering, is there an opportunity with the A&D market opening to monetize some of those, or how should we think about that part of your inventory?

That's a good question. Excellent question, and we appreciate it and appreciate your compliments. Yeah, we are always evaluating property sales, and I'm going to ask Ken Bedeker kind of to comment on that in general for the company.

Sure. Thanks, Bill. You know, we're always high-grading our portfolio and divesting of those properties with minimal double premium potential remaining, and we've actually sold about $7 billion in assets over the last 10 years. And we will continue to high grade our assets as we see the market giving them fair value.

And certainly, you know, in the last few years, it hasn't been a seller's market. But it is, it will turn as people get short of inventory. And we think that the premium, the single premium assets that we have, you know, even those are probably some of the best inventory in the industry today. So those certainly have a lot of value.

Okay. And they don't, with $60 oil and, you know, costs where they are today, they don't compete for capital within your program?

Yeah, that's correct. 30% rate of return at 40 doesn't compete in our program right now. It needs to be a 60% rate of return at 40 flat. It's definitely a huge shift in our returns, and that's what we've been talking about for the last several quarters in our script and in our slides to detail a lot of really good information. But certainly the shift to double premium is, we believe, by far the highest reinvestment standard in the industry, and it is a clear separator for EOG. and it will drive exceptional performance for the company going forward.

This concludes our question and answer session. I would like to turn the conference back over to Mr. Thomas for any closing remarks.

In closing, our excellent first quarter results are a testament to EOG's ability to generate significant shareholder value. We're proud of all of EOG employees and their outstanding contributions to continuously improve the company. Our excitement about EOG's ability to improve returns and increase value has never been greater. So thanks for listening, and thanks for your support.

The conference has now concluded. Thank you for attending today's presentation, and you may now dismiss.