Good day everyone and welcome to EOG Resources Fourth Quarter 2019 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 the Chief Financial Officer of EOG Resources, Mr. Tim Driggers. Please go ahead, sir.

Thank you and good morning. Thanks for joining us. We hope everyone has seen the press release announcing fourth quarter and full-year 2019 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 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 US 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; Ken Boedeker, EVP Exploration and Production; Ezra Yacob, EVP Exploration and Production; Lance Terveen, Senior VP Marketing; and David Streit, VP, Investor and Public Relations. For the call this morning, we want to cover three topics. First, Bill Thomas will review the characteristics of EOG that have contributed to our long-term sustainable success; second, I will discuss our financial strategy; and third Billy Helms will review the outstanding 2019 operating performance and the 2020 plan. Here's Bill Thomas.

Thanks Tim, and good morning everyone. In times of uncertainty, EOG's sustainable business model is well suited to navigate a volatile environment. In fact, we are more confident in EOG's future today than we've ever been in the history of the Company. With our strong balance sheet and flexibility, EOG is better positioned now, both financially and operationally to weather the storms than it's ever been in the past. Our operational performance last year was the best in the Company history, and we believe EOG's performance in 2020 will be even better than 2019. With an industry-leading return on capital employed of 12% in 2019, we beat our plan in every respect. Capital spending was below plan, volumes were over plan, and per unit operating expenses declined more than forecast. We grew oil production at a lower cost per barrel than ever before and delivered on our goal of double-digit returns and double-digit growth in a modest oil price environment. The Company also generated nearly $1.9 billion of free cash flow, defined as our discretionary cash flow less our total cash capital expenditures. That cash flow funded the retirement of $900 million of debt and the payment of $588 million in dividends. We accomplished all this with oil prices averaging $57 a barrel. Today, due to our confidence in the future performance of the Company, we are increasing the dividend again for the third year in a row by another 30%. With this increase, our dividend has more than doubled since 2017 and represents an annual return of cash to shareholders of more than $800 million in 2020. Our confidence in this Company's future is based on two unique characteristics of EOG. The first is our culture and the second is our premium investment standard. These two qualities drive our…

Thanks Bill. EOG had outstanding financial performance in 2019, demonstrating the resiliency of our business. Our 2019 return on capital employed was 12% with oil averaging $57 per barrel for the year and with meaningfully lower NGL and natural gas prices compared to 2018. EOG generated discretionary cash flow for the full year of $8.1 billion and invested $6.2 billion in exploration and development expenditures, resulting in full-year free cash flow of $1.9 billion. Proceeds from asset sales in 2019 contributed an additional $140 million. We paid $588 million in dividends and retired $900 million in debt. Cash on the balance sheet at year end was $2 billion and total debt was $5.2 billion for a net debt-to-total cap ratio of 13%, down from 19% at the end of 2018. The power of our premium well strategy can be seen in our financial performance for the last three years. We established the premium hurdle rate in 2016 and the strategies began paying off the very next year. Beginning in 2017, we have averaged 14% return on capital employed, a return measure that can be directly calculated from our financial statements using GAAP earnings; generated nearly $4.6 billion of free cash flow while growing US oil production by 64%; paid out $1.4 billion in dividends or 30% of free cash flow; and retired nearly $1.9 billion in debt, cutting our debt-to-cap ratio by more than half from 28% to 13%. Our focus at EOG is creating long-term shareholder value. The clearest way to realize this goal is to grow the business value of our Company over time while at the same time protecting that value through commodity price cycles. How do we do this? We compound attractive corporate level returns through disciplined growth while ensuring the Company remains profitable in lower…

Thanks, Tim. Let me first start by saying that I'm extremely proud of the efforts and achievements of our talented employees for their tremendous execution in 2019. EOG delivered more oil for less capital in all four quarters of 2019. For the full year, we increased US oil production 15%, producing 5,000 barrels of oil per day more than we initially estimated at the start of 2019 with CapEx that was near the low end of the guidance. We achieved this with four fewer rigs and two fewer completion spreads than originally planned. Driven by efficiency improvements across our operation, total well cost declined 7% in 2019. Internally generated improvements came from every area of our operations, sparked by innovation from EOG's creative, decentralized organization. In our drilling operations, a good example is our premium drilling motor program. The program implemented in the Permian, led to a 50% reduction in motor failures in 2019, generating a cost savings of $20,000 per well. We are now implementing this program in the Rockies and Mid-Continent areas, joining the Eagle Ford, which has had a similar program for some time. Our drilling teams are also delivering performance improvements more consistently, which reduces downtime. As a result, our drilling times improved 17% across our 36-rig program. Our completion teams also delivered outstanding improvements in 2019 due to the employment of electric frac fleets and the use of diverter material. As a result, overall well performance increased and completion costs were down 15%. Our drilling and completion advancements last year were the primary reason we delivered higher production with lower capital cost expenditures. CapEx savings driven by well cost improvements in 2019 allowed us to invest more money in infrastructure projects and acreage acquisitions than the original plan. Investments in infrastructure like water handling systems…

Thanks, Billy. In closing, I will leave you with these thoughts. First, our 2020 plan is set to perform even stronger than 2019. With improved capital efficiency, we are set to deliver strong high-return growth and investments that will strengthen the future of the Company. We are particularly excited about cost reduction and drilling a significant number of wells on several new large exploration plays that we believe will continue to improve our inventory. We see no end to improving the Company in 2020. Second, EOG's unique return-focused and innovative culture has proven for decades to deliver significant shareholder value. Our culture continues to improve and we'll continue to drive our future success. Third, our strict premium investment hurdle is the most stringent in the industry and a significant and unique competitive advantage that allows EOG to be one of the lowest cost operators in the global energy market. And finally, EOG has positioned better than ever to be the leader in ROCE and deliver double-digit growth with significant free cash flow through the commodity cycles. We are more confident and excited about our future now than we've ever been before. Thanks for listening and now we'll go to Q&A.

[Operator Instructions] And the first question comes from Doug Leggate with Bank of America. Please go ahead.

And Bill, may I say thank you for the disclosure on sustaining capital that we've been asking for. It makes life a lot more transparent and a lot easier for us to figure out how we think about valuations so appreciate that on Slide 9 of your deck. My question is on the inventory. I guess, the Slides 12 and 13, again terrific disclosure, but can you just help us understand how - what the process is, excuse me - what the process is to translate the - I think you called it conversion potential of some 5,000 locations and what that visibility looks like longer term, because the only knock on your stock now that we constantly here is, while as you continue to grow and increase the pace, that inventory life is going to shrink. So, applying some kind of annuity valuation becomes problematic unless you've got that visibility. So, what is the process and what is the debt, I guess, is the question.

Yes, our inventory, when I think about EOG's inventory life, it's probably last on my list of things to worry about I'd say because the Company has just historically and continues to be a prolific generator of inventory. And since we started premium in 2016, we've just steadily increased the inventory up and currently it's 10,500 locations and we have an additional 5,000 locations that really are just on the verge of converting into premium. And I'm going to ask Ezra to give a little bit more color on about how we do this and then maybe talk about some of our additional inventory through our exploration.

Yes, Doug. This is Ezra. Thanks for the question. As Bill pointed out, we have identified 10,500 premium locations right now which at our current pace of drilling represents about 13 years of drilling and then those 5,000 locations that you both pointed out with the conversion potential would add another six years at the current pace. So, going back to the conversion potential, I think, as Billy noted in the opening remarks, this past year, we were able to reduce well costs across the Company by approximately 7% and that's really the number one driver of converting those well locations and that's something we've done over the past four years is be able to lower well cost every year through not just reduced contract pricing, but dominantly through our increased operational efficiency and applying innovative technologies and capturing different parts of the value chain. So, that's the first way that we look to expand the inventory, the premium inventory. The second thing we do, which is a bit more challenging, of course, is through our exploration effort and that's an organic exploration effort where we're currently trying to add not only additional premium locations. We've really improved the quality of the locations. So as you mentioned on Slide 12, we've shown what the medium rate of return of our current premium well inventory is there at 58% rate of return on that premium price deck of $40 flat oil, $2.50 natural gas. So, what we're trying to do is really increase that and we're currently for the past 12 months to 18 months we've been leasing in - across 10 different prospects and as Billy mentioned in the opening remarks, we look to be testing about six of those this year and we're very excited about the progress of those exploration prospects and the potential that they could add to the inventory.

Thanks for the detailed answer guys. My immediate part B to that real quick, the maintenance capital number, what's the decline rate that goes with that?

I'll ask Billy to comment on that.

It's - yes, the decline on the base production's 32%, Doug.

So my follow-up then is just a real quick one. Billy, it's also for you, I guess, because you talked about you wouldn't increase spending in a higher oil price environment. Well, I guess, the question that kind of follows from that is, are we seeing then a reset in your sort of base planning assumptions for the commodity because even we believe your stock is very undervalued here and I wonder if share buybacks becomes a consideration at some point.

Yes, Doug. This is Billy. I may give you some thoughts and then maybe Bill want to answer, but since you directed the question to me, I guess, yeah, the point is that we're going to stay disciplined on our capital program. So, we'll certainly adjust downward if commodity prices show that this is going to last for a sustained period of time, but if they do rebound, we will not outspend our capital that we've allocated for this year and we're going to stay disciplined with that. And the reason is, we're going to - as we've stated in the past, we only continue to fund at a point which we can continue to get better. We have a lot of different agendas to try to improve this year and including the exploration projects we talked about and many of the other projects we've got under way, and we certainly want to see those through. So, if oil prices suddenly jump way up, we're not going to rush out and increase capital. So, our plan is really set based on conservative outlook at the time we set the plan and that's not going to change as we go through the year.

Yes, Doug, I'll just comment on your question about would we consider share buybacks and just reiterate our priorities really have not changed. Number one, as Tim talked about, the best way to create business value is there's no question about it anyway, you want to run it, is reinvesting a high rates of return and that's what we're committed to and that's what we really want to stay focused on. The next priority is sustaining and growing the dividend and we believe the dividend is the best way to return cash to shareholders over the long term and obviously we have been - demonstrated a very, very strong commitment to that this year and previous year. So, that's the way that we want to continue to focus on returning cash to shareholders.

And our next question will come from Arun Jayaram with JPMorgan. Please go ahead.

Yes, Bill, I was wondering if you could comment on how EOG is thinking about some of the demand impacts from the coronavirus and the state of the oil market today and what would be the Company's game plan if we did move into an environment where we have sustained oil prices caught in the low $40s for some bit of time?

Yes, Arun, certainly this is a huge world event and it's developing and we like everybody else is watching really daily the developments around the world and we certainly hope and pray it's a short-term event, but if it turned to a longer-term of that, as Billy said, we're in a fantastic position, Number 1. We got a great balance sheet and we are committed to that and that's certainly been a strength of EOG for years and years and years. And so, that puts us in a great position. And then, we're very flexible. We have an operational ability to adjust activity and I think I'll let Billy comment a little bit more about that, maybe some of the specifics.

Yes, Arun. So, the way I would add to that is we have the capability to adjust our rig activity and frac fleets down to really be in line with our sustainable CapEx or our maintenance capital numbers. So, we set out a plan that really allows us to capture the highest performing rigs and frac crews in the market, but we have a tremendous amount of flexibility to adjust downward if we need to. And so - and the same would apply to our allocation of capital to our infrastructure spend and another things. We have the same capability to adjust that downward if needed. So, we'd just be patient here and watch to see how the market unfolds and adjust accordingly.

Bill, in your prepared comments you talked about some of the infrastructure spend, which is designed to lower your operating cost. I was wondering if you could maybe give us a little bit more color on the magnitude and the level of these investments. What exactly are you investing in on the infrastructure side?

Yes, the infrastructure is just very critical to build out that infrastructure ahead of the drilling, because it has significant well cost reduction and which certainly increases returns. It has a significant influence on lowering operating costs significantly also and it allows us to, I think, certainly market our products and get our products online, reduce flaring, just all kinds of tremendous benefits. So, really important to stay ahead of that. And maybe Billy you want - you can give a little bit more color on some of the specifics.

Yes. On the specific side of that, Arun, as Bill mentioned, there is a lot of things that we'd like to fund and I would - all of these projects have a direct impact not only on our capital cost in the future of our drilling program, but also lowering our unit operating costs. So, I would point you to Slide 16 in our deck that shows in the last several years, we've reduced our cash operating expense tremendously, 33% percent since 2014. A large part of that decrease came from investment in infrastructure. It allows, even as Ezra talked earlier about our inventory and our ability to convert these wells to premium, part of that cost goes back to investing in infrastructure. So, there are things like the most economic part of that would be getting trucks off the road and reducing our transportation cost, getting water on pipe, oil and gas infrastructure in place, well ahead of the drilling program so that we minimize not only our capital cost for that upcoming year and future years, but also the biggest impact on lowering our full year's LOE and certainly our transportation costs. So, that's largely what it entails.

The next question comes from Neal Dingmann with SunTrust. Please go ahead.

Morning, Bill and team. My first question's on your 2020 plan, specifically, how fluid is your allocation to the various high-return plays along with how actively you might change your well spacing and other development plans based on what the commodity prices do?

Neil, this is Bill. On the last point, I don't think we would change spacing that much based on the commodity prices, really, we're already basing our economics on all of our drilling on $40 flat oil. So, we're - even with a drop in price, we're still have a very strict reinvestment hurdle. So, that part we wouldn't really change too much. As far as the plays, the reason it's really easy for us to, I guess, ramp down activity is that we're in multiple plays. We're developing six plays out of multiple divisions. So, you just take one rig per play which is an easy reduction out of each play. It's really easy to do and it makes it really fluid. If you can take two rigs out of each play, that's 12 rig. So we haven't - because of our decentralized organization and multiple plays, it's not that difficult to systematically reduce as the commodity price changes.

No, that makes sense. And then my second question, Bill, for you or the team is just on infrastructure. You all suggest in the release that you would allocate a bit more to infrastructure. I'm just wondering, will there come a time down the road where your infrastructure reaches a size where you can consider monetizing or does this remain too critical in keeping your costs lower?

I'll ask Billy to comment on that one.

Yes, I would say that the infrastructure is just a critical component of our development activities on a go-forward basis and it really doesn't make sense for us economically or financially to monetize that because it is a big part. As I mentioned earlier, it's a big part of driving our unit costs down and improving our returns long term. So, we plan to - we look at each case independently to see where it makes sense for us to invest in that infrastructure versus others and a large part of that goes back to our need to control how we get those products to market also to capture the biggest prices in not only domestic markets, but also be able to export that as we need to.

The next question is from Brian Singer with Goldman Sachs.

My first question's on the Eagle Ford shale. There has been much made about the shift from east to west within the portfolio and concerns over falling EURs. On Slide 42, you highlight the extent to which in well costs were lower in the Eagle Ford, which arguably offset some of that last year about 11% well cost reduction. In 2020, your target for well cost reductions is a bit more modest at 4%. And so, wanted to ask how you see well productivity playing out in the Eagle Ford in 2020 and your outlook for the trajectory for capital efficiency there.

Yes Brian. Thank you for the question on the Eagle Ford. I think the main thing that's really important on the Eagle Ford is that due to the dramatic cost reductions we continue to have there, our economics remain very, very, very strong. And so, Ken's the expert on the Eagle Ford. I am going to ask him to comment on specifics there.

Yes, Brian. As we've moved to the west over the last few years, we've continued to lower the cost basis in the Eagle Ford and improve our returns. If you look at the cost basis, so everything that it takes us to find, develop, produce and market our oil there, you can see that cost basis has continued to reduce even though our percentage to the - going to the West has increased by several percent over the last few years. Out in the West, it's less structurally complex so we're able to drill longer wells and as we bring our cost reductions into that area along with our improved targeting and better completion strategies, we expect those costs to continue to reduce. Our field crew there in the Eagle Ford is just doing an outstanding job in driving those costs down.

And so when net-net in 2020 then, just a follow-up - just - do you continue to see at or better capital efficiency when you think about the cost reduction potential and then how you see your well performance?

Yes, we would expect to see actually better capital efficiency in 2020 than we saw '19 in the Eagle Ford.

Great, thanks. And then my follow up is with regards to acreage acquisitions. You talked about that and some capital being earmarked for that this year again. Can you characterize what stage you're in there, the acreage that you - or the capital that you're earmarking, is that capital that is for - based on well results that you know of that are already meeting your return thresholds or is this acreage that is essentially being bought in advance of testing? And then, one of the items that's also on your list for use of excess cash is premium property additions and perhaps you can give an update on how that market looks.

Brian, I'm going to ask Ezra to comment on the acreage.

Yes, Brian. This is Ezra. As far as the acreage in the exploration plays, we really spent, I think, as I just mentioned the last 12 months to 18 months putting together acreage in what we consider to be the highest quality kind of the Tier 1, if you will, parts of these exploration plays and we've been doing that at relatively low cost, really, well under $1,000 per acre I'd say across all of those plays. And we've gotten at least six of those plays as we mentioned to a point where there will still be some additional acreage to put together, but we're at the point on those plays where we plan on drilling and testing those this year. And then, we will still be leasing across some of the other exploration plays as well and, obviously, with these exploration plays, just to keep our competitive advantage up, Brian, I don't want to say too much more than that.

Yes, Brian, as far as the maybe bolt-on acquisitions, we really don't plan on doing any significant bolt-ons this year, maybe as a few little really small ones in our exploration plays, but with the commodity prices what they are, we're going to be really careful with cash and make sure that we focus it on things that are going to generate super high returns.

The next question will come from Leo Mariani with KeyBanc. Please go ahead.

Just wanted to get a sense of whether or not in this type of market, which clearly has been quite weak, it feels a little bit like 2016 right now. Whether or not you guys would take advantage of your strong balance sheet to maybe look at some chunkier bolt-on M&A type situations like you did with the Yates back then.

Yes, I think we just talked about that. No, we don't really have any big plans to do any bolt-on or larger deals. We've been very fortunate as Ezra talked about. Over the last year and a half we've accreted a significant amount of acreage in a number of what we think are very, very high quality plays and we have accreted that at very low cost per acre. And so, we're going to be focused on testing those this year. How we increase in the exploration spend this year is all in drilling. So, we're really set up to test those this year and we're excited about adding new higher quality potential and improving our inventory through our exploration efforts.

And I guess just with respect to the well cost reductions, looks like you guys beat your target last year 5%, came in at 7%, new target here at 4% in 2020. Just wanted to get a sense of where do you kind of see as the high level kind of big drivers and I guess none of this is service costs in terms of what can lead to those cost reductions here in '20.

I am going to ask Billy to comment on that one.

There are several factors. It's not one single thing as you ought to imagine. We're seeing certainly some softness in the tubular side. We'll be probably be about 8% lower on tubulars this year relative to last year. Certainly on the completion side of the business, that's probably the area of the biggest decreases we'll see this year and a large - part of that still is on sand cost that could be down again this year just due to mainly getting sand even closer to the wellhead than we did last year. And we are even seeing some softness in drilling rig rates. So, the biggest thing though, I think, that's going to drive that is just our continued push. So, those all were service-related issues. The biggest cost drivers will be on efficiency gains. We just continue to get better and better at everything we do, drilling wells much faster, the use of diverter, improving our completion efficiencies and lowering our well cost, those things all drive the biggest majority of our savings year-over-year.

And our next question will come from Paul Cheng with Scotiabank.

Two quick question. I think, Billy you have said that you may, if in the event that you need to reduce the activity level that you could be very easy to just maybe take out one rig per play, but is that the plan or that you will be more looking at, say, a particular play you're going to see more of the one or two is going to be target first or that you will be targeting on the infrastructure that we saw development spending?

Yes, if I understand the question, Paul, you're asking where would we reduce, would there be any specific plays that we would reduce more other or we would maybe look at infrastructure reduction? Billy can you comment?

That's correct.

This is Billy. Just to give you a sense, we have a lot of flexibility in all areas. So, we would look at each part of our plan and accordingly adjust as we need to. So, it would be not only just drilling. It could be infrastructure projects as well. And we like to get out ahead of the drilling just to put in the infrastructure to maximize their benefit, but if we slowed down drilling in an area, we will certainly slow down infrastructure spend as well. So, that's one way to think about it. As far as one play relative to the other, as Bill mentioned earlier, it's really easy to adjust each play down and we'll certainly make those decisions when we see the market unfold. So, as we mentioned earlier, we'll just be patient and kind of watch to see what happens before we start making any adjustments.

The second question just, I think, the Cheniere LNG export term just starting up soon. So, can you tell us that, I mean, how much you pay for the toll and that the physical terms there? - going to get ramped to the 440 million cubic feet per day.

First off, related to the contractual terms just due to the confidentiality, we can't disclose that, but I can walk you through a little bit of when that started up. So, we actually did start with Cheniere. We're excited about that and we actually had our first lifting on January 20. And so, that is 140 million a day that will be linked JKM. So that's started up in January. And then that will ramp up to 440 million a day with 300 million of that being linked to Henry Hub. So, that's currently what's in place today.

Our next question will come from Scott Gruber with Citigroup. Please go ahead.

Yes, just coming back to the infrastructure question that some of your spend on facilities G&P and environmental projects to be about 20% of the total this year. How should we think about that over time? Where to kind of go at some of these strategic investment slate?

Yes, Billy will comment on that, Scott.

We typically budget every year the overall infrastructure for our facilities in G&P. It's usually about 15% to 20% of our typical plan and this year we've allocated a little bit more closer to the 20% number as you just mentioned and that varies year to-year depending on where we are in the development of each play and our need for infrastructure to expand those plays and get our cost reductions that we anticipate. So this particular year, it's a little closer to the high end, but I think in general, it's usually between 15% and 20%.

And then, appreciate the disclosure on the maintenance CapEx. How should we think about the infrastructure percentage within that figure?

It would probably...

Go ahead.

Yes, it would probably be on the low end of that number, 15% to 20% that I mentioned earlier would be on the low end of that. Certainly we would - focusing on our core areas where we have a little need for additional infrastructure expansion and that would just remind you that that's a maintenance capital number for this year based on keeping this year's number flat.

The next question comes from Joseph Allman with Baird.

So, on the dividend, what analysis do you do to determine that the dividend is sustainable and to determine how much to increase it. I know Tim commented on this earlier, but like how many years do you look out, three years, five years, 10 years or more and what are the factors that you model and what type of stress testing do you do?

Yes, we'll ask Tim to comment on that.

Yes, when we model it, we model it on several different scenarios, but as far as how far out we look, we look out about five years because that's really about as far as you can look out as far as the strip goes to get an idea of what - how to model commodity prices and we stress test it on just about every metric you can imagine, to come up with a recommendation to the Board on where to move the dividend. And so then, as you can imagine, there is a lots of discussion around all that analysis and the Board either agrees with us or doesn't and then we move forward with that increase.

That's helpful, Tim. And then, on Slide 9, the maintenance CapEx slide, I assume that that's a dynamic metric. So, could you describe how that might change over the next few years?

We'll ask Billy to comment on that.

So, it's important to understand how we come up with the maintenance capital number to start with. It's a very detailed bottoms-up approach, starting with this year's plan, our 2020 plan and then scaling that down in each one of our plays to make sure we maintain kind of flat growth in each one of our premium plays. So, that's kind of the approach. So each year certainly, depending on what our volumes were, would determine what that level of maintenance capital would be needed to replace or at least maintain the prior-year's production number. So again, this number would fluctuate just depending on what kind of target we're trying to hit, but we would approach it the same way. And then that - it's pretty important to note too that that covers both capital and the dividend at $40. So, it's a pretty good number. It just demonstrates the improvement in our capital efficiencies and basically, this assumes also that we don't see any improvements in either our production performance or additional gains and lowering well cost. So, it's taking the existing conditions as we have today.

Our next question will be from Bob Brackett with Bernstein Research. Please go ahead.

You mentioned that inventory was last on the list of things that you worry about. Could you go to the top of that list and talk about the things specific to EOG that you worry about?

Well, Bob, of course, oil prices would be number one. It's always number one. So, that's the most difficult part in our volatile environment that we deal with. Really, the Company is in such fantastic shape, I don't really spend a lot of time up at night worried about the direction of the Company. As we said, we've got tremendous confidence in our ability to really continue to have very, very, very good success. And the main - and the reason is simply what we stated before is our culture. I mean we have a - I think a very unique incredible culture and the bottom and the value of the Company is bottom-up driven. It's not me driving it. It's not me making decisions on where to drill the wells or how do get the costs down. It's literally every person in the Company is a business person and we give them - they have the data. They have the ability to analyze it and make decisions, and it's just really the results that we have in the Company are very sustainable because they come from a 1,000 different places. And so, that takes the pressure off of me and it really is just a fantastic organization. So, that really is the basis of our confidence.

Okay. So, not much to worry about from that perspective. Thank you for that.

And our next question will come from Jeanine Wai with Barclays. Please go ahead.

This is Jeanine. My first question is on inventory quality, back to that Slide 13, where you show rate of return versus your premium well count at different oil prices. For that curve, what does the distribution look like by basin and can you point to kind of where 2020 - where that sits on the curve?

On the curve, the distribution of the wells, the returns is about the same at each one of our plays. It looks very much the same. We have single premium, double premium, triple premium wells in really every play that we're developing. And then our 2020 plan, the returns on our 2020 plan would reflect about the median there. When we look back on our scorecard for last year, our 2019 plan, our returns at the current prices are at $40 flat oil. We're about the median. So, that represents the median returns there which are 53% at $40 - I mean, 58% at $40 flat and an incredible 83% after tax rate of return at $50 flat oil prices are about the returns that we're getting on our drilling program.

That's really helpful. My second question is on the balance sheet and maybe we're just being a little too nuanced here but we noticed that there was a slight change in messaging on the debt reduction program from I think the slide went from targeting $3 billion in debt reduction to quote evaluating options for current maturity. So, can you just provide a little color on this whether you have any new debt or cash target in response to the macro view and I guess the reason why we're asking is because we had thought that getting through your $3 billion debt reduction program was potentially a trigger for doing share buybacks or other things of the free cash flow.

Yes, Tim will comment on that.

Yes. So, there was a slight change there and the reason was where we're at in the commodity cycle. We will pay off our two bonds that come due this year. One is due April 1 and the other's June 1. They are $500 million each. So, obviously we'll pay those off. We'll then evaluate where the market is currently and where it looks like it will be going long term to see where commodity prices are going and make a decision, a prudent decision whether or not to refinance those bonds or not. The goal is still to pay off $3 billion over that period of time, but we have to be prudent and look at the conditions at the time and decide where to go.

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

Well, first of all 2019 was the best operating performance in the history of the Company and that is just due to - just what we've been talking about is to everybody in EOG. So, thank you to everybody in EOG for doing a fantastic job. We're excited about carrying that momentum into 2020. The Company's got a great balance sheet. We've got operational flexibilities we've talked about, industry-leading premium inventory and a unique EOG culture. So, the Company is set to weather the storms and weather the downturns and to continue to deliver strong results in the future. We're really excited about where we are and where we're headed. So thanks for listening, and thanks for your support.

And thank you, sir. The conference has now concluded. Thank you for attending today’s presentation. You may now disconnect your lines.