Good morning, and welcome to the Q3 2020 ConocoPhillips Earnings Conference Call. My name is Laura, and I'll be the operator for today's call. At this time, all participants are in a listen-only mode. Later we will conduct a question-and-answer session. [Operator Instructions] Please note, this conference is being recorded. I will now turn the call over to Ms. Ellen DeSanctis. Ms. DeSanctis, you may begin.

Thanks, Laura. Hello, and welcome this morning to our listeners. I'll first introduce the members of the ConocoPhillips executive team who are on today's call. We have Ryan Lance, our Chairman and CEO; Matt Fox, our EVP and Chief Operating Officer; Bill Bullock, our Executive Vice President and Chief Financial Officer; we have Dominic Macklon, our Senior Vice President of Strategy, Exploration and Technology; and Nick Olds, our Senior Vice President of Global Operations. Ryan will open this morning with some prepared remarks, and then the team will take your questions. Before I turn the call over to Ryan, a few reminders. In conjunction with this morning's press release, we posted a short deck of supplemental material regarding the quarter onto our website, that's available for your access. Next, we will make some forward-looking statements this morning based on current expectations, as well as statements about the proposed business combination announced last week between ConocoPhillips and Concho. A description of the risks associated with forward-looking statements and other important information about the proposed transaction can be found in today's press release, all of which are incorporated by reference for purposes of this call. We'll also refer to some non-GAAP financial measures today and reconciliations to the nearest corresponding GAAP measure can be found in this morning's press release and also on our website. Thank you. And now I will turn the call over to Ryan.

Thank you, Ellen. And good morning to our listeners. Before we get into our third quarter results, I'll take a few minutes to address last week's announcement of our combination with Conoco Resources. We spent a lot of time talking to the market over the past several days, and I'm pleased to say that the feedback has been positive. By the way, earlier this week, we added some annotations to our transaction deck for clarification. Today's call is a great opportunity to reflect on our conversations and reiterate the compelling merits of the transaction for both sets of shareholders. I'll start at the highest level. Our announced transaction with Concho combines two widely recognized leaders in the sector. ConocoPhillips has been a recognized leader in the returns on and returns of capital model for the business. And Concho has been a recognized leader in the Permian pure-play class. Yet while we're both best-in-class companies on a stand-alone basis by scaling up our existing returns focused business model, we are stronger and more investable within the sector, characterized by frequent price cycles, industry maturity, capital intensity and ESG focus. We'll be a nearly $60 billion enterprise that is uniquely positioned to create sustained value by embracing what we believe are the three essential future mandates for our sector. And these mandates are, first, providing affordable energy to the world, second, committed to ESG excellence, and third, delivering competitive returns. We believe the transaction accelerates our ability to successfully and simultaneously deliver on all three of these mandates. That's how we will win. Now let me take these mandates one by one in the context of our transaction. In all future energy scenarios, we know the world will need hydrocarbons as part of the energy mix for a long time, even as we see increasing adoption of low-carbon energy sources. However, we also recognize that the energy transition means the winners will be those companies with resources that can be affordably developed in a transition - in any transition scenario, including a less than two-degree scenario. That's the reason we've always been committed to having the lowest cost of supply resource base in the industry. The company will have a 23 billion barrel resource base with a cost of supply less than $40 a barrel. Conoco gets the benefits of our global, diverse and lower capital intensity portfolio attributes. ConocoPhillips gets the benefit of adding some of the best resources in the world. And by the way, we studied rock quality everywhere. Now let's move on to the second mandate, a commitment to ESG excellence. In conjunction with last week's transaction, we announced we're adopting a Paris aligned climate risk framework. We're the first US-based oil and gas company to do so. Our framework includes specific emissions intensity reduction goals, a commitment to no routine flaring, permanently installed methane monitoring and advocating for a well-designed carbon price in the US. This framework is in service to our ambition to reach a net zero operational emissions target by 2050. Now we've announced in our engagement meetings if this framework included the portfolio effects of the Concho assets. The explicit answer is no. We were preparing to issue our new climate risk framework before the transaction was agreed. However, we see the addition of Concho's assets as being consistent with and accretive to these goals. The production emissions of the US unconventionals are among the lowest GHG intensity assets in the world. So the addition of these resources will be a benefit to our projections, plans and targets. Now the third mandate, delivering competitive returns is an imperative for attracting and retaining investors to the sector. Our company has been all about returns, and that will change. In fact, the combined company will be uniquely positioned to deliver on the proven returns focused proposition we know investors a lot from our sector because of several advantaged attributes and demonstrated priorities. For example, as I just described, the transaction creates a massive, resilient, low cost of supply resource base. I discussed this as part of mandate one, but also add that low cost of supply is best assurance, by definition, for delivering competitive financial returns through price cycles. After the deal closes, we'll publish our combined cost of supply curve. I have no doubt it will be best-in-class. By the way, we've been asked about how we view risk in the event of a change in leadership in Washington. Our view is that while it might create some headwinds for the industry, our company's global diversification and a mix of private, state and federal leases in the US assures that we are competitively positioned for that outcome, and we accounted for this potential risk in our evaluation of the overall transaction. Diversification and low capital intensity matters. And as I just mentioned, we preserve those portfolio characteristics. Adding Concho's unconventional assets into our portfolio will not make a material difference to our base decline rate. That means we retain our diversification and low capital intensity advantage for the benefit of both shareholders. We’ll apply our disciplined and consistent approach to future investment programs, capital will be allocated first on a basis of cost of supply and then based on secondary criteria, such as flexibility, capital intensity, asset optimization, affordability and free cash generation. And our expanded Permian program resulting from the transaction will be integrated within the total company plan to optimize overall outcomes and value. The combination creates greater visibility on earnings expansion and free cash flow generation. Factoring in our announced $500 million targeted cost and capital savings, the transaction is accretive on all key consensus financial metrics, including earnings, free cash flow and free cash flow yield. Finally, our strong balance sheet, plus free cash flow generation means we're even better positioned to give investors what they want from this business, returns of capital. The transaction enhances our ability to meet our stated target of returning more than 30% of our CFO to our owners annually. And this target isn't an ambition. It's what we've been doing for the past four years. In fact, we returned over 40% of our CFO to owners over that period, and it will remain a key part of our future offering. The bottom line, this transaction creates a best-in-class competitor of scale to thrive in a new energy future that is compelling for shareholders for both companies. Now a few comments on what to expect next. Our S-4 filings should be filed in the next couple of weeks, and we expect the transaction to close in the first quarter of 2021. Integration planning is already underway. Dominic Macklon will lead the effort for ConocoPhillips and Will Drow [ph] lead the effort for Concho. Both sides are excited and committed to a very successful integration. As part of the integration planning, we'll begin to evaluate how best to optimize our future investment programs. We would expect to announce pro forma CapEx for next year shortly after closing. But directionally, on a stand-alone ConocoPhillips spaces, we remain cautious on the pace and timing of recovery. So as a place to start, we're currently thinking we enter 2021 CapEx at a level that is roughly similar to this year's capital, meaning little to no production growth on a stand-alone basis. Of course, we retain the flexibility to adjust as the year progresses. We have the capital flexibility, the balance sheet and the cash on hand to respond as necessary to changes in the macro while meeting our capital return priority. And that brings me to a few comments on the third quarter results. It's certainly been a revolver [ph] year for the business, as we all know. The company took some significant actions to respond to the downturn, including production curtailments. And over the past couple of quarters, we also carried out our major seasonal turnarounds, saw a bit of noise in the second quarter and third quarter numbers. But by the end of the third quarter, the curtailment program was behind us, the seasonal turnarounds were complete, and the underlying business was running very well. As you saw this morning's release, third quarter results were in line with expectations. We've reinstated guidance that you should think of - and you should take the fourth quarter as the new baseline for 2021 capital and production. Those I just mentioned, that's subject to ongoing monitoring and market conditions. We look forward to keeping you updated on our integration progress and our future plans for the business. And finally, we hope everyone is safe and well. And now I'll turn it over to the operator for Q&A.

Thank you. [Operator Instructions] And our first question comes from Phil Gresh from JPMorgan. Please go ahead. Your line is open.

Yes, hello. So first question, just wanted to ask about the quarter here. It looks like there are some moving pieces around cash flows, affiliate distributions and some other factors there. So I was wondering if you could give a little bit more color there and help us think about how you would define the clean CFO in the quarter?

Yes. Thanks, Phil. I'll let Bill Bullock can answer that for you. Thanks.

Hi, Phil. So yes, for the quarter, cash from operations, ex working capital was about $1.230 billion. And we had a couple of one-time benefits in the quarter, a legal settlement and an audit settlement totaling $130 million of that. But we also had curtailments in the quarter of about 90,000 barrels a day. So the foregone cash flow for that would have been about $150 million of cash. So if you think of a clean run rate number for the quarter, a good place to be thinking is about $1.250 billion for the quarter. Now you asked about equity distributions. We did have a distribution from APLNG in the quarter. We received distributions through the second quarter of about $500 million from APLNG. And for the remainder of the year, we're expecting a little under $200 million in the fourth quarter. That would give a full year distribution of somewhere around $680 million to $700 million for the year.

Okay. Great. Very helpful. I guess this kind of dovetails in my second question, which is we continue to get some questions here around this pro forma CFO guidance that you provided. And so if I look at the results, you just talked about the $1.25 billion and what Concho reported the other night, which I think ex-hedges, was around 500. Perhaps you could help us bridge these results, which I think are about $41 WTI to the 7 billion, $40 WTI guidance that you provided?

Yes. Thanks, Phil. I know there's a number of moving parts there, as you described in. Yes, we've had a few people point out that they bought the 7 billion at $40 a barrel for the combined company, looked a little bit light. So that we've seen in the third quarter, if you adjust for Concho's hedging benefits and what Bill just described on our equity affiliates, I think you get something closer to the mid to high 7s at $40. So maybe I'll let Matt add a little bit of color to those details.

Yes. If you look at the clean third quarter for both companies, Bill explained it would imply somewhere between 7.5 and 7.8 at $43 a barrel. Now that the range is basically that is on the uncertainty in the equity affiliates distribution. If we've got similar distributions to this year, we'll be at the top end of that range. And these numbers also include the pro forma assumption that we get, the full year of expected cost savings that we announced, which was $350 million of cash, and that's what shows up in these numbers. There's also the $150 million of capital, that doesn't affect CFO directly. Does that help, Phil?

I hope so.

Thank you. Our next question comes from Doug Terreson from Evercore ISI. Please go ahead. Your line is open.

Good morning, everybody.

Good morning, Doug.

One of the hallmarks, Ryan, of Conoco and Phillips before the merger and even after the split in 2012 has been corporate agility is the way I'd like to think about it. And the ability to create value in strategic transactions over the near and medium-term periods. And on this point, while you guys have been pretty clear about the operating and capital cost benefits that you're going to get, as well as some of the enhancements that you're going to get from a higher quality investment portfolio. My question is whether there are areas that you're optimistic about that may or may not be as obvious that stand to deliver further upside, areas that you're really confident about similar to situations that you've had in the past with other transactions? And then second, what are the two to three most important things that you think that the new management group brings to the organization? So two questions.

Yes. Thanks, Doug. I'll maybe start and let Dominic add a few comments. You're right. When we put out the synergy number, we see a lot of other synergy numbers that people put out there, and it seems like a fair amount of arm waving. We want to be pretty specific about the $500 million that we described. But if you look at the second page, which I think is what you're alluding to a little bit, but I can let Dominic add on. Yes, we fully expect that we're going to get additional opportunity either through price uplift or various other forms to add incremental value to this transaction. Dominic, maybe you could describe a little bit of what the integration team is going to be looking at.

Yes. Thanks, Ryan. And Doug, thanks for the question. Actually, we're very focused on delivering the $500 million that we have put out there as a commitment. But certainly, we see opportunity beyond that. I think we kind of outlined those in our deck. I think just to talk more about those specifically. I think the ones that we're most optimistic about. On the marketing side, Concho typically sells our product to the wellhead. We sell further down the value chain to improve realization. So we have a very strong commercial group, ConocoPhillips. So we're certainly excited about that. Concho have been doing extremely well in the Permian on the drilling completion costs. The performance has been excellent and they're further down the learning curve on us there. So we do expect to see that to accelerate the performance on our acreage too. And of course, we expect improved performance across the Lower 48 from sharing best practices and technologies between Eagle Ford and the Permian and the Bakken and so on. So definitely, operational efficiencies. And then on the supply chain side, obviously, we're going to have increased purchasing power, scale, flexibility. So we're anticipating upside in all these areas and some additional areas to that we'll be working on in the coming months here. So Will and I are already talking about these, we're pretty excited about it, and we'll look forward to see how these develop through next year.

And maybe your last question, Doug. So Dominic mentioned well over and then what Tim -- what we really appreciate out of what they bring to our company is some incredible Permian expertise and experience. They have the networks. They have broader and deeper networks than we really have in the Permian, given their long time association and presence there and what Tim has built is two or three goals added in what he's done over the last 30 years in the Permian Basin. And I'll tell you, I've had a lot of conversations with CEOs over the course of the last couple of years. And when I've come to appreciate, Tim shares a passion for this business and a vision for what it's going to take to be successful over the next decade and beyond. That is really consistent with my view or our view of what it's going to take to really succeed and beat the competition. And then I'd say, finally, probably, we're both very committed to a successful deal. And we're both committed to getting the secret sauce that is ConocoPhillips, combined with the secret sauce that is Concho. And make something that's even better going forward.

Thank you. Our next question comes from Neil Mehta from Goldman Sachs. Please go ahead. Your line is open.

Great. Thanks guys. I appreciate it. Thanks for taking my questions. So the first is a follow-up on distributions, including from APLNG, but just equity affiliates broadly. Just how do you think about that, you made that we shouldn't expect that to be ratable. Can you talk about different oil price levels? And how we should be thinking about modeling those distributions coming into the business?

Yes. Sure, Neil. This is Bill. I think as you're thinking about equity affiliates, we've talked in the past how they aren't ratable. You should be thinking about the distributions from APLNG, in terms of being more significant in the second and fourth quarter and lighter in the first and third. But as you think about going into next year and you look at more like strip prices for next year, if you're thinking of the range of $600 million to $800 million, from equity affiliates at those kind of pricing, that's going to -- that gives you to the ballpark. It obviously depends on, how they're performing in terms of the markets. And how we're optimizing our capital over an APLNG, but that will get you pretty close.

Great and Ryan as a follow-up…

And just as a reminder, Neil, we do have a sensitivity for that in our price deck, for the pricing.

That's right. That's right. Yes.

In the supplemental materials we included today.

Okay, guys.

Yes, go ahead, Neil. You had a second follow-up?

Yes. It was really just about Alaska. And I know we're a couple of days away from the election, that this is probably a very sensitive topic, but just sort of your temperature on the Fair Share Act. And just in general, your message around Alaska. And you think about the cadence of spend and investment there?

Yes, you bet. I'll let - Matt's been following that closely. I have too, but that's got an answer.

Yes, Neil. I mean, as you know, there are really three moving parts. They're topical just now, there's the ballot initiative to increase the production tax. There's the status of the Willow project. And there's the impact, if any, of a change in administration, if that happens on federal land permitting. So I probably should talk about three of them, so that we can hopefully clear up Alaska with this one question. So as you know, the ballot measure would impose a tax increase in production. That's going to have two problems to adverse effects. It's going to reduce the competitiveness of investment in Alaska. And it's going to increase, uncertainty and instability. So that's not going to be good. And we've got years of development opportunities left in Alaska, but a shift of capital from Alaska elsewhere is going to be rational, if taxes will increase. I mean this is a production tax. And what your tax more, you get less of. So, that should be expected, if those advocating for this. And voting for the proposal should understand that. And we've been pretty clear, so that we were to avoid any doubt in Alaska, that if the passes, drilling in the big three fields, the targets of the tax increase, it's not going to resume in 2021 and maybe beyond that. So the Alaska jobs, contract labor, all the associated services are going to be adversely impacted by this change. And the contractors, the unions, all the other businesses up there understand this, and they've proposed the most part opposing the change in the tax regime. But it's now up to elector to decide and elections of consequences. So we're getting down with a wire here, and we really feel we have to be clear with the Alaska voters. On the Willow project itself, we passed a big milestone earlier this week. We got a favorable record of decision from the BLM after it's more than two years of process. So that keeps us on track with our project timeline. And it's worth understanding that, that permit was received under the 2013 integrated activity plans. So the National Petroleum Reserve the rules that were set under the -- the administration. So they should stand up well to scrutiny under changing administration if that happens. So we're working towards the concept selection and moving to feed by the end of this year, so just assumes the ballot measure fails and taxes are not increased. If it passes, we'll need to reconsider the timing because it will -- directly, targeted by the tax increases, there's going to be a knock-on effects in the oil fields because of the lack of available capital. And then the last one is the federal land and permitting in Alaska. The more generally, if there's a change in administration, we would expect that to have a relatively limited impact on us. I mean although 65% of our acreage is on federal land only represents about 5% of our production. Now some coming production, GMT 2, in particular, is on federal land, but it's still underway. First production will be at the end of next year. So we don't expect that it will be affected at all. Willows on federal land, of course and -- but neither Willow or GMT 1 or GMT 2, the federal land drill sites is anything other than conventional to simulation techniques. So if fish is about fracking there, they shouldn't be influenced by that. So I guess, we've been clear with Alaska about the implications of Ballot Measure 1. We expect any implications of the change in administration in D.C. to have a relatively limited impact on us.

Thank you. Our next question comes from Jeanine Wai from Barclays. Please go ahead, your line is open.

Hi, good morning, good afternoon everyone. Thanks for taking our call.

Good morning, Jeanine.

Good morning. Maybe sorry just one more on Alaska, if I could, real quick, following up on Neil's question. It's a little bit different. But I mean, last year, on the Analyst Day, you talked about how Willow would be contingent upon selling down 25% of your position in Alaska? And we know that you need resolution on Ballot Measure 1 first. But is that 25% sell down, still the case now that you have Concho assets in the portfolio? And then maybe just on that, for the Ballot Measure 1, we know it's a citizen ballot measure. And do you think that it could be likely that the legislature would potentially overturn any decision?

Yes, Jeanine, this is Matt again. We didn't really say it was that the explicitly tie a Willow decision to sell down, but we're still anticipating that we will to sell down in Alaska. We just slowed the timing of that down until we get some of these uncertainties resolved. So it's still on the current so we'll make an adjustment to equity in Alaska. But we may still continue to proceed with the project. In the meantime -- so the timing of the project isn't contingent on the sell down, I guess, is what I'm saying. On the ballot measure one and then can the – could the legislature overrule that? Not really. Not going to take a little bit of time for that. They would have to come up with an alternative that was substantially similar or the – so it wouldn't be – sound unlikely that we would overturn the lock stock and barrel.

Okay. Great. That's really helpful. Thank you very much. My follow-up question is just on the cash allocation priorities. And you indicated in your prepared remarks that 2021 CapEx should be about similar to 2020 with little to no production growth. The strip moves around a lot. It's kind of moving against us all today. But is the right way generally to think about it is that, in the mid-40s threshold, that threshold that you have for production growth, it's a hard and fast criteria that needs to be met? Or are there just a bunch of other considerations that we would need to factor into the decision-making process?

Yes. I think we -- as I tried to describe, we basically use cost of supply. And I think, as we think about the forward curve or – and thinking about our plans for 2020. And again, I mentioned those on a stand-alone basis for ConocoPhillips. That's kind of how we're thinking about it going into next year. It's just not cost of supply, but it's also what kind of cash flow are we projecting to make. And we have the benefit of a very strong balance sheet, so we can use some of that, should we need to. But, certainly, we'd be also trying to balance the cash we're making with the CapEx that we're spending in the dividend that today satisfies 30% of our return criteria and more, given the kinds of prices that we're seeing. So, certainly, some headwinds into the commodity price outlook right now, some with COVID resurgence and demand certainly hasn't started to recover. And depending on what NOPEC or OPEC does on the supply side and what the U.S. response is, we're watching all of that really closely to make sure that whatever program we put in place for 2021, we can balance with the cash flows that we expect and make sure that we're investing in the lowest cost to supply things that we have in the portfolio only.

Thank you. Our next question comes from Josh Silverstein from Wolfe Research. Please go ahead. Your line is open.

Yes. Thanks guys. Maybe just gearing off that last question there. You've mentioned that for Concho stand-alone CapEx, it would be very similar on a year-over-year basis. What would the Concho stand-alone volumes look like relative to the fourth quarter 2020 volumes under that scenario?

Yes. Josh, we would be – we'd expect, under that scenario, to be similar to fourth quarter or second half of the year sort of rates, at that sort of level. So that would be roughly 4.3 is what we're spending this year, which is a bit above our sustaining capital. So, I want to take that opportunity to clear that up. Because flat production and yet above our sustaining capital. So let me try and maybe explain why that's different. So if we were going to execute a long-term sustaining strategy for the company, the – we need about 3.8 for ConocoPhillips stand-alone. And that was sustained production at one point, but roughly a bit below 1.2 million barrels would be. The - but with the low-cost of supply that we have in the portfolio, we don't expect that our long-term strategy will be to simply sustain production. The investment opportunities are too competitive for that. But what Ryan is really indicating is that we could execute a tactical sustaining program, much like we have this year and start 2020 with that sort of tactical sustaining program and then see how demand recovery and supply response shape out. And the distinction between us or tactical and strategic sustainable program is tactical sustaining program, we would still keep production flat, but we wouldn't completely shutdown projects like Willow or exploration activity. But those things will still continue with the anticipation that they ultimately we'd move away from simply sustaining back to some modest growth. So, those are the things that we're working through just now in the plan. But as Ryan said, we shouldn't expect us to communicate 2021 capital guidance certainly for the combined company to sometime after the transaction closes.

Yes, I would add, Josh, we have a lot of flexibility with the balance sheet, which is why if we go in at a similar level of capital to this year, it may be flat to modest growth, so it doesn't necessarily equal flat production at the capital level going in next year. But that's something we'll continue to watch as the macro evolves around us.

Excellent. And then you mentioned that the Lower 48 assets, or, I guess, the unconventional assets, the lowest emission part of the portfolio and the Concho assets only add to that. I'm curious what the highest asset is? And does any sort of the international portfolio? Do you think about M&A in that regard as well, maybe those candidates that kind of accelerate towards getting to your 2030 path?

Yes. So the highest emissions assets in the portfolio, just now in the operated portfolio, it's really is oil sense. That's why we're so focused on looking at ways to bring oil sands emissions down and we've got a lot of irons in the fire there. We're going to extend our non-condensable gas injection, which brings down steam oil ratio by keeping heat in the reservoir. And of course, it's a steam oil ratio that drives the emissions intensity. We're also going to be deploying more of flow control devices. That brings the steam ratio down we're moving to add some sustaining pads. As some of the pads get older, their steam oil ratio increases. When you put new pads on, they can very low steam oil ratio. And there's other technologies that we're looking at there as well. So, what we're doing basically across the board as we're looking at all of our greenhouse gas intensity across every asset that we have. And we're asking ourselves, what can we do to cost effectively bring that down. And that's what our - we bring that process together in what we call our marginal abatement cost curve. And we have about 100 projects, and they're just now -- some of them are desktop exercises and feasibility studies. So, we spent about $90 million this year between capital and operating cost on those projects. But we look across the whole asset base ways to bring that down.

And our targets, Josh, that we establish the 35% to 45% reduction that doesn't require major portfolio changes to go do that. So, we're not talking about having to sell certain assets that Matt described. That's things that we have identified inside the portfolio to work on with the portfolio being relatively constant over this time.

Yes. It's actually -- that's a good point, Ryan. It's mostly driven by the fact that we're -- it's a sort of strategic shift in where we're investing. We're investing in lower greenhouse gas intensity places like the unconventionals in the U.S. and Canada, like in low Alaska, which is a very low-intensity as well. So the percentage of our production, that's very low-intensity increases with time. And when you combine that with reducing the emissions intensity of our existing assets like the oil sands, that's how we've delivered the reduction in the emissions intensity over the next 10 years. It's not …

And Matt described, sort of, the cost and capital is small amounts to get this plan. We're not talking about spending hundreds of millions of dollars of capital to go deliver this. This is small projects that are currently baked into our plans.

Thank you. Our next question comes from Roger Read from Wells Fargo. Please go ahead. Your line is open.

Thank you. And good morning.

Good morning. Roger.

Just I'd like to kick on really kind of a follow-up, what we're talking about with Josh there. As you think about 2021 CapEx, roughly flat, and you said you ought to be nimble next year for what comes. What would be the things you would be looking at? I mean, presumably not simply oil price up or down. I mean, it's – I assume it’s some macro factors. Maybe help us kind of understand some of the signals you might look for getting more optimistic in ‘21?

Yes. I mean it would be macro. We have to see how the demand response to what looks like a slower response than people were hoping for, especially with Europe and possibly in the U.S. coming. So we have to just be cautious about that. We have to look at how the Russia and OPEC can respond. I mean they have a move coming up to the end of November and see when we get back to sort of drawing down inventory. So the beauty of our position is that we've got incredible flexibility. We've got the low breakeven price of cover for flat production and to cover the dividend. That's sustained from -- the two companies together. So we're actually having that flexibility and the ability to respond to what the market is going to give us is very helpful. So we're not going to rush headlong into trying to grow production into this. So it doesn't make any sense to us. We'll see how things play out here over the next several months, and then we'll make adjustments between our low breakeven and our balance sheet, we will be in a very good shape to assess that as we go through.

Okay. Thanks.

And I would add, Roger there, sorry, I would add, Roger, that well, it's not so much even just what's the strip look like or what it looks like for next year. It's sort of a longer-term trajectory back to what we believe is a reasonable mid-cycle price. And we'll be reassessing what that mid-cycle looks like, depending on where the demand and supply fundamentals start to kind of shake out with the U.S. title going down, what happens to the election and Alaska and then it's going to make imminent amount of sense as we combine with Concho to optimize and figure out what the right level of activity is between the two companies. So the -- you're right, there's a number of factors that will be putting into the mix as we look at not only 2021 plans, but the next couple three years look like as we -- as this business recovers back to a mid-cycle and whether it overshoots or undershoots.

It's oil industry. So it will definitely do one or the other and maybe both. One quick kind of follow-up unrelated to the first question, but related to the merger. Some of the savings that you cited were going to be exploration appraisal spending that doesn't have to happen. I was curious for the assets that you won't be spending E&A money on in the near future, do they just go back into the resource base? Or is that something that maybe becomes more likely to be disposed of monetized in a different way?

Yes, Roger, it's Dominic here. Thank you. So what we said was that we will continue focusing our exploration effort on our existing business units, such as Alaska, Norway, Malaysia. So that will allow us to about half of exploration capital from 300 to 150. So those areas, such as down in South America, Colombia, Argentina and so on, we will be working sort of managed exits from those areas. Of course, we have a lot of value there. We see a lot of value. There's a lot of good acreage there. But we'll be working to preserve value as we think about how to exit those areas in the future. So more a question of dispositions in a managed way, rather than those resources staying in the portfolio. We have such a strong portfolio. We will with Concho that we just think it's appropriate that we focus the exploration effort.

And we manage those there -- there's not excessive capital employed associated with those assets. But we'll -- as Dominic said, we're going to do everything we can to monetize them as best we can.

And we don't have any resource associated with any of those assets in the moment in our supply curve. There's no resource associated with them.

Thank you. Our next question comes from Scott Hanold from RBC Capital Markets. Please go ahead. Your line is open.

Thanks. Could you give us some color on U.S. natural gas price has been pretty strong? And is there ability for Conoco to flex for that a little bit? Or is there -- where is your opportunity outside of associated gas? Or is that really the opportunity?

Yes. I think the main opportunity for us, Scott, is associated gas. We probably have a little bit in the Anadarko Basin, but that's not capturing a lot of our capital right now. So it mostly, for us, we're still a pretty big marketers. So we were moving over 8 Bcf of gas a day. So we see a lot of that. So we're getting some uplift on the commercial side of our business with some of the transport capacity we have that takes gas from the Permian to the West Coast and down South to Arizona and even into Mexico. So that's how we're kind of taking advantage of the kind of market as we see it today. And but on just an absolute production side, we're not looking to ramp up dry gas, and it's mostly coming from the associated gas with the unconventional production.

Yes. Could you quantify some of the marketing benefits you all see?

So I’ll let Bill, he's head of our Commercial Organization to maybe provide a bit of color there.

Yes, sure. So Scott, we have a very active commercial organization. Ryan mentioned that we're moving a little over 8 Bcf a day. We're the fifth largest gas marketer in the U.S. and we provide a variety of sources to various customers ranging from asset management agreements to offtake agreements, and that provides an ability to, one, have insight into the market and also to gain margin cross moving across pipelines. So, we continue to look at that and continue to move, and we're shipping gas for a profit. So, of that 8 Bcf a day, 500 million cubic feet a day of it is ours, the rest of its third-party volume. And so we're in and out of the market on both sides on a daily basis.

Thank you. Our next question comes from Doug Leggate from Bank of America. Please go ahead, your line is open.

Thanks. Good morning everybody. I wonder, Bill, maybe I could start off with you and ask you to maybe elaborate a little bit on Ryan's comments around the potential election outcomes. And I'm thinking specifically about tax. I'm sure you guys have looked at this. But the thing that strikes me is a little bit disturbing is the potential for a minimum 15% P&L tax that puts NOLs under a bit of a spotlight. So, I'm just wondering if you guys have thought about that any scenarios that you've run outcomes that you might expect?

Yes. Sure. We've certainly taken a look at the various tax proposals out there, including Biden tax proposal. There's two primary elements of that, that would impact us. Doug, the first one is, obviously, the change in the corporate tax rate from 21% to 28%. And the second one that would be fairly significant would be removal IDCs, particularly in our capital program and needing to depreciate those over time. Those are the two main aspects as we look through it that really would have an impact on us.

Yes. I guess I should have been clear. I was talking about a potential Biden administration. And maybe as a follow-up then, I know it's something that is a little bit too obvious, but we don't maybe ask it enough. Ryan, when yourself and when Matt put together the title wave scenarios and all the other scenarios that you laid out at the Strategy Day, we've now seen what we think is a lot of the signs of a bottom cycle coming to a bottom, if you like, with consolidation, your sales being part of that. How does this -- what you're seeing right now beyond COVID influence your thoughts on longer term supply demand as you think about scenario planning? I'll leave it there. Thanks.

Yes. Thanks Doug. I'll maybe add a few comments, and Matt can jump in as well. But yes, we spent a lot of time trying to think about what the trajectory of the recovery looks like. And probably a couple of competing factors. We certainly see demand recovery, we uncertain whether it gets fully back to 100 million barrels a day, but probably taking a bit of time to get there. And then I think equally important and maybe overlooked a little bit is what's happening on the supply side, maybe masked little bit today by DUC inventory, but when the declines and the declines are hitting in and it was masked by curtailments coming back on, there's going to be a drop in U.S. supply as well. So, I can -- Matt can probably chime in and describe a little bit about the net effect to the scenarios that we're thinking about as we debate our capital program and how much to put back to work.

Yes, Doug, I mean, the -- I think you and I have discussed this in the past. The -- if you look at the -- our expectations for the exit rate for this year for U.S. trade oil, is somewhere between 6.5 million and 7 million barrels a day, and we'll be that Europe and as we approach the end of the year. So that compares to over 8 million barrels a day in December of last year, 8.2. And to some extent, that dropped flatters to deceive because people were still bringing wells on in the first quarter and into the second quarter. The -- so there's a significant underlying decline going on here. When we model this, and I know that you do too, the strip prices in the low 40s. We think the industry is going to struggle to maintain flat production at December's rates through '21 and into '22. '21 will get a bit of a lift from the DUCs. But people are going to live within cash flow. There's going to be a real challenge to see trade oil at 7 million barrels a day. And it's likely to be less than that in 2021 and 2022. If you compare that to the trajectory we were on, that's at least 4 million barrels a day less than the pre-COVID trend. And that's just U.S. trade oil. And we respond more quickly here because of the decline rates in the capital flexibility. But the similar issues are happening elsewhere. So, although there is definitely uncertainty and how much the demand effect will be and it's likely to be less of a demand effect than the supply effect, certainly over the next few years. So the premise of your question initially -- are we setting up for the bottom of a cycle here? I certainly feels that way to us. And now exactly when it terms, it will be dependent upon the demand at the COVID and how OPEC doing the short term, but we're certainly setting up for a tighter supply-demand balance in a year or so, if not before that.

Yes. So short, medium term, all about demand, medium, longer-term supply starts to enter the picture, as Matt described. And we have a couple, 2, 3 scenarios around how we think what that slope and trajectory look like.

Thank you. Our next question comes from Paul Cheng from Scotia Bank. Please go ahead. Your line is open.

Hey guys, good morning.

Good morning, Paul.

[indiscernible] If we look at the trading and optimization or commercial operation, historically, that the U.S. looking at that as a core center mainly for facilitation, the European, on the other take a more aggressive approach and looking at it as a profit center. And they seems to be doing quite well and have a good logic to trade around your physical asset. So from that standpoint, will Conoco should look at that operation and see whether that it could allow you to have a higher performance and higher return? Or that you think facilitation is better, and you don't want to take on that swing in earnings and the higher risk? So that's the first question. The second question, with the less for argument if you decide your longer-term 10-year plan has changed due to different market condition and as such that your future growth rate is going to be lower. With the addition of the Concho asset, what other asset in your portfolio will take more of the backseat and seeing lesser capital investment. If you can, say, the number one, number two on that, if that's possible? Thank you.

Yes. So let me take the first one, and maybe Matt can chime in on the second one on the capital investment. So the first one, yes, we're looking at the commercial space. And with the addition of Concho, it is a -- as you described, Paul, kind of a cost center inside the company, but we're looking at expanding that as we think about the future and what the Concho assets bring, I think as Dominic described earlier, they saw mostly at the wellhead, so we got some opportunity to add value there to both the gas and the oil side. We're building more export capacity as a company and in fact, have done some sales to -- point sales to customers where we take the middleman out of the equation, and we found that quite margin enhancing as we go forward as well. So with the growing US production that we have with the combination with Concho, it absolutely represents a big part of how we can expand the commercial organization and think about it differently, too. I mean, Bill described the market share that we have already and that's only going to get bigger as we go forward. So, we're looking for more contribution from the commercial side across the whole portfolio. Maybe, Matt, if you want to take the capital allocation as a result of integrating the Concho asset. Again, I go back to our -- it's a cost of supply primary criteria, but Matt can provide a bit more detail about what might fall out.

Yes, Paul, as you know, what we do is we try to optimize each of our individual parts of the portfolio to get the optimum pace, using a set of decision criteria, but the most important of which is that we're not going to invest above an incremental cost of supply of $40 a barrel, and we described that some length back in November of last year. And so, we look at the optimization of each, and then we put it together, and we maybe make a few adjustments, but we're trying to honor the optimum in each of the assets. There is flexibility across the portfolio and the pace we can adjust the pace of any given project by euro, so we can adjust the rate at which we increase the ramp in the number of rigs. So I wouldn't call out any specific asset. If we decide that we want to grow at 2% instead of 4% or something like that the flexibility across the portfolio to do that and still on our criteria, that wouldn't bust the criteria. The obvious places are Lower 48, Alaska. That's where the flexibility mostly exists, and maybe in Canada as well. But I wouldn't really call out a specific asset, but we're trying to do and we're trying to optimize across the portfolio. But the issue is, if you're not optimizing across the diverse portfolio, when you're maximizing the value that the diversification brings you, so we -- that's what we're trying to do is to make sure that we're winning each of these assets out there optimal.

Thank you. Our next question comes from Jeoffrey Lambujon from Tudor Pickering. Please go ahead. Your line is open.

Good morning. Thanks for taking my questions. My first one is on ESG and the Paris aligned climate risk strategy. And I think your commentary earlier answered a lot of what I'm looking for with the oil sand specific and just your comments on investment decisions. But is there anything incremental you can share at this point on other operational changes that you're undertaking and focusing on for the broader portfolio? Just trying to get a sense for the scope of some of these projects you mentioned, again, in terms of what's in focus, whether that's new technology around monitoring, retrofitting equipment for emissions control or what have you?

Yes. Thanks. It's Dominic here. I'll just take that. Recently, I was very much involved in the Lower 48, and there's some really some important progress we're making there. I think we announced a couple of things here, along with our new Paris aligned strategy. One was a commitment to zero routine flaring. And that's the World Bank initiative there. So we're committed to that. And the other one was the introduction of continuous methane monitoring. So this is a real breakthrough for us. We're able to do this now at a very reasonable cost. And we're able to now, basically, on our key sites, we'll have this implemented. I think it will have about 65% of our Lower 48 production covered by early next year. And this technology, at very low cost, allows us to sample the emissions around sites, looking from ethane every 15 seconds. And from that, we can respond very quickly to any aberrations that we can address very quickly. So those are a couple of really important initiatives for us that contribute to that overall commitment we have to reduce our GHG intensity by 35% to 45% by 2030. And we really have first mover on this, as you'll know, Jeff. We were the first U.S. based oil and gas company to set a GHG intensity target, and we're the first U.S. based oil and gas company to commit to being Paris aligned.

Thank you. Our next question comes from Pavel Molchanov from Raymond James. Please go ahead. Your line is open.

Thanks for the question. Two quick ones, both regarding Europe, I guess it's about 10% of your gas volumes. No one is accustomed to seeing North Sea gas prices below $3 an MCf, but we've had that the last two quarters. Is that a COVID related demand situation? Or is there something more structural in that market?

I think that -- this is Bill. I think that as you think about that, that's more of what we see of COVID related to demand related issues right now as we think about long-term, the macro supply around the world, we would see markets tend to have more arbitrage off of the U.S. Gulf Coast with LNG markets, starting to move volumes both into Europe and into Asia as the incremental barrel. So I think that what you're seeing is a short-term response to supply-demand and not a long-term structural change.

Okay. And a follow-up on that, in about six weeks, the European Climate Law will be approved by the EU leaders, which will make the North Sea, the one part of your portfolio that is covered by a net zero mandate. Does that change anything in terms of how you're thinking about that asset, given the decarbonization targets for the EU as a whole?

No, not really. I think we're continuing to make adjustments. What we're left with in the Europe portfolio is our Norwegian assets. And it's some of the lowest carbon intensity assets we have that are offshore and looking at other options to continue to reduce our emissions through electrification and additions there. But as we look at it, it's minimal addition to the cost of supply and it's quite manageable and Norway still is very competitive in the portfolio.

This is Ellen. We'll go ahead and take our last question, if you don't mind. Thank you.

Absolutely. Thank you. Our next question comes from Phillips Johnston from Capital One. Please go ahead. Your line is now open.

Hi, guys. Thanks. So just one question to me and it relates to your future return of capital to shareholders. In the last five years, you guys have repurchased a little over $10 billion worth of stock at an average price of around $62 a share. So at today's share price, the paper loss in that program is pretty substantial. I realize you guys plan to repurchase more stock here in the fourth quarter. But I wanted to ask if there's any appetite at the Board level to scrap the idea of share repurchases. And instead, pursue a fixed plus variable dividend strategy that would target paying out a certain percentage of your free cash flow directly to shareholders each quarter.

Yes. I think the most important thing is your last piece of that. We are targeting over 30% of our cash back to the shareholder. That's what we've committed to and delivered on in excess over the last three to four years, since we kind of came out to reestablish a new value proposition for this business. And I think the dividend today is certainly covering a large share of that. Also think that buying our shares back at this kind of level is an important thing to do too, because shares are certainly well undervalued. It's certainly relative to where we think mid-cycle price should be. So I don't think we'll give up on share repurchases completely. You made a real point. I mean we wanted to buy our shares through the cycle. And this was a pretty significant downturn with curtailed production and the like going on in the second quarter. So we did suspend for a while. We wanted to restart up because the benefit to really buying your shares is not just buy them. When you're at mid-cycle price, we continue to buy them through the low end of the cycle because that's what brings down the average cost of your shares, obviously. So we still think it's going to be a piece of our return to shareholder pie. And the question begins, what happens on future excess returns when if there's another big cycle, and we start to exceed our mid-cycle price call and we've had conversations around that with the market, and we continue to look at all the different ways to do that and continue to be open in all the different ways to do that. But at this 10 seconds, the dividend more than satisfies our return to shareholders.

Thank you. We have no questions at this time. I'll turn the call back over to Ellen. Thank you.

Great. Thanks, Laura. Thanks to our listeners, by all means, reach back to us if you have any follow-up questions and we really appreciate your interest and support in ConocoPhillips. Thank you.

Thank you. And thank you, ladies and gentlemen. This concludes today's conference. Thank you for participating. You may now disconnect.