ConocoPhillips

Good morning and welcome to the Q3 2020 ConocoPhillips earnings conference call. My name is Zanara and I'll be the operator for today's call. At this time all participants are in a listen only mode. Later we'll conduct a question and answer session. During the question and answer session if you have a question please press star then one on your touch tone phone. Please note this conference is being recorded. I will now turn the call over to Ms. Ellen DeSantis. Ms. DeSantis you may begin.

Thanks Zanara. 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 Macklin 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 referenced 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 Concho 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 Purmean PurePlay class. Yet while we're both best in class companies on a standalone 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 for the cost of supply less than $40 a barrel. Contro 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've 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 U.S. 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 U.S. This framework is in service to our ambition to reach a net zero operational emissions target by 2050. Now we've been asked in our engagement meetings if this framework included the portfolio effects of the Contro 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 Contro's assets as being consistent with and accretive to these goals. The production emissions of the U.S. 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 won't change. In fact, the combined company will be uniquely positioned to deliver on the proven returns focused value proposition we know investors want from our sector because of several advantage 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 the 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 our mix of private, state, and federal leases in the U.S. 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 contras on conventional 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, consistent approach to future investment programs. Capital will be allocated first on the basis of cost of supply and then based on secondary criteria such as flexibility, capital intensity, asset optimization, affordability, and free cash flow 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 creative 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 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. RS4 filing 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 Macklin will lead the effort for ConocoPhillips and Will Giroux will lead the effort for Concha. 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 standalone ConocoPhillips basis, 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 standalone 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 volatile 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. So 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 alignment with expectations. We've reinstated guidance that you should think of, and you should take the fourth quarter as the new baseline for 21 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's safe and well. And now I'll turn it over to the operator for Q&A.

Thank you. We will now begin the question and answer session. If you have a question, please press star, then one on your touchtone phone. If you're using a speakerphone, you may need to pick up the handset first before pressing the numbers. Once again, if you have a question, please press star, then one on your touchtone phone. Waiting on standby for any questions. And our first question comes from Phil Gresh from JP Morgan. Please go ahead. Your line is open.

Yes. Hello. 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 a clean CFO in the quarter.

Yeah, thanks, Phil. I'll let Bill Bullock answer that for you. Thanks. Hi, Phil.

So yeah, for the quarter, cash from operations, ex working capital was about ,000,000. And we had a couple of one-time benefits in the quarter, a legal settlement and an audit settlement totaling ,000,000 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 ,000,000 of cash. So if you think of a clean run rate number for the quarter, good place to be thinking is about ,000,000 for the quarter. Now, you asked about equity distributions. We did have a distribution from APL&G in the quarter. We received distributions through the second quarter of about ,000,000 from APL&G. And for the remainder of the year, we're expecting a little under ,000,000 in the fourth quarter. That would give a four-year distribution of somewhere around $680,000 to ,000,000 for the year.

OK, great. Very helpful. I guess this kind of dovetails into my second question, which is, you know, 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 and what Contra reported the other night, which I think ex-Hedges was around $500,000. Perhaps you could help us bridge these results, which I think are about $41 WTI to the ,000,000 WTI guidance you provided.

Yeah, thanks, Phil. I know there's a number of moving parts there, as you described. And yeah, we've had a few people point out that they thought the ,000,000 a barrel for the combined company looked a little bit light. So now we've seen the third quarter, if you adjust for Contra's hedging benefits and what Bill just described on our equity affiliates, I think you get something closer to the mid to high sevens, you know, at $40. So maybe I'll let Matt add a little bit of color to those details.

Yeah, if you look at the clean third quarter for both companies, Bill explained the errors. It would imply somewhere between $7.5 and $7.8 at $40 a barrel. Now the range is basically based on the uncertainty in the equity affiliates distribution. If we've got similar distributions to this year, we'd be at the top end in that range. And these numbers also include a pro forma assumption that we'd 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'll take that as a yes.

Yeah, hope

so.

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

Good morning, everybody. Good morning, Doug. One of the hallmarks, Ryan, of Conoco and Philips before the merger and even after the split in 2012 has been corporate agility is the way I like to think about it and the ability to create value and 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 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.

Yeah, thanks, Doug. I'll maybe start, let Dominic add a few comments. You're right. You know, 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 the second page, which I think is what you're alluding to a little bit that I can let Dominic add on, is we fully expect that we're going to get a lot of money from the 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.

Yeah, thanks. Thanks, Ryan and Doug. Thanks for the question. You know, obviously 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 outlined those in our deck, I think, just to talk more about those specifically, I think the ones that we're most optimistic about. You know, on the marketing side, Contra typically sells a product to the wellhead. We sell further down the value chain to improve realization. So, you know, we have a very strong commercial group, ConocoPhillips, so we're certainly excited about that. You know, Contra have been doing extremely well in the Permian on the drilling completion cost. The performance has been excellent and they're further down the learning curve than us there. So we do expect to see that accelerate, you know, the performance on our acreage too. And of course we expect, you know, improved performance across the lower 48 from sharing best practices and technologies between Eagleford and the Permian and the back end 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, you know, upside in all these areas and some additional areas too 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 Will and then what Tim, you know, 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's built is, you know, two or three goes at it and 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. What 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. So and then I'd say finally, probably, you know, we're both very committed to a successful deal and we're both committed to getting the secret sauce that is Conoco Phillips 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 from Goldman Sachs. Please go ahead. Your line is open.

Great. Thanks, guys. Appreciate you guys taking the questions. So the first is a follow up on distributions, including from APLG, but just equity affiliates broadly. Just how do you think about that? You made a comment in the deck that we shouldn't expect that to be ratable. You talk about different oil price levels and how we should think about modeling those distributions coming into business.

Yeah, 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 APLG in terms of being more significant in the second and fourth quarter and lighter in the first and third. But as you think about them going into next year and you look at more like strip prices for next year, if you're thinking of the range of $600 to $800 million from equity affiliates at those kind of pricing, that's going to get you into the ballpark. Obviously, it depends on how they're performing on terms of the markets and how we're optimizing our capital over an APLG, but that'll get you pretty close.

Great, Bill. Ryan has 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.

And the supplemental materials we included today.

Go ahead, Neil. Do you have a second follow up? Yeah,

it was really just about Alaska. And I know we're a couple of days away from the election, but it's 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.

Yeah, you bet. I'll let Matt's been following that closely. I have to, but Matt's got a good answer.

Yeah, Neil, as

you know, there are

really three moving parts that are 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 all 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. And that's going to have two problems, two 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. We've got years of development opportunities left in Alaska, but a shift of capital from Alaska to elsewhere is going to be rational if taxes are increased. I mean, this is a production tax and what you 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're being pretty clear to avoid any doubt in Alaska that if the measure passes, drilling in the big three fields, the targets of the tax increase is not going to resume in 2021 and maybe beyond that. So the, you know, 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 opposed, for the most part, opposing the change in the tax regime. But it's now up to the electorate to decide and elections have consequences. So we're getting down to the wire here and we really feel as if we have to be clear with 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 more than two years of process. So that keeps us on track with the project timeline. And it's worth understanding that that permit was received under the 2013 integrated activity plan for the National Petroleum Reserve. And those are rules that were set under the Obama administration. So they should stand up well to scrutiny under a change in administration if that happens. So we're working towards a concept selection and moving to feed by the end of this year. Of course, this assumes the ballot measure fails when taxes are not increased. If it passes, we'll need to reconsider the timing because although Willow isn't directly targeted by the tax increases, there's going to be knock-on effects on the other fields because of the lack of available capital. And the last one is the federal land permitting in Alaska. 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, it only represents about 5% of our production. Now, some coming production, GMT2 in particular, is on federal land, but it's well underway. First production will be at the end of next year. So we don't expect that will be affected at all. Willow's on federal land, of course, but neither Willow nor GMT1 or GMT2, the federal land drill sites, use anything other than conventional simulation techniques. So if this is about fracking, they shouldn't be influenced by that. So I guess we've been clear with Alaska electorate about the implications of ballot measure one. We expect any implications of the change in administration to in DC to have a relatively limited impact on us.

Thank you. Our next question comes from Janine Wise from Barquays. Please go ahead. Your line is open.

Hi. Good morning. Good afternoon, everyone. Thanks for taking your call. Good morning, Janine. 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 one first. But is that 25% sell down still the case now that you have contra assets in the portfolio? And then maybe just on that for the ballot measure one, 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?

Janine, this is Matt again. We didn't really say it was the explicitly tie a Willow decision to a sell down. And they but we're still anticipating that we will do a 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 cards that 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 kind of could the legislature overrule that? Not really. I'm not going to take a little bit of time for that. They would have to come up with an alternative that was substantially similar. So it wouldn't be unlikely that they would overturn it, that they 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, 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 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?

Yeah, I think we, you know, as I tried to describe, we basically use cost to supply. And I think as we as we think about the forward curve, we're thinking about our plans for 2020. And again, I mentioned those on a standalone basis for ConocoPhillips. That's kind of how we're thinking about it going into next year. It's just not not cost to supply, but it's also what kind of cash flow are we projecting to make? And, you know, 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 percent 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. With COVID resurgence, some 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, you know, we're watching all of that really closely to make sure that whatever program we put in place for 21, 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 Wolf Research. Please go ahead. Your line is open.

Thanks, guys. Maybe just giving off that last question there. You mentioned that, you know, for Conoco standalone CAPEX it would be very similar on a -over-year basis. What would the Conoco standalone volumes look like relative to the fourth quarter 20 volumes under that scenario?

Yeah, Josh, we would 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 the opportunity to clear that up because flat production and yet above our sustaining capital. So let me try and explain why that's different. So if we were going to execute a long-term sustaining strategy for the company, we'd need about 3.8 for Conoco Phillips standalone, and that would sustain production at roughly a bit below 1.2M bals a day. 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 responses shape out. And what the distinction between us, our tactical and strategic sustaining program, is in a tactical sustaining program, we would still keep production flat, but we wouldn't completely shut down projects like Willow, our exploration activity. Those things would still continue with the anticipation that they ultimately would 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. As Ryan said, you shouldn't expect us to communicate 2021 capital guidance, certainly for the combined company, until sometime after the transaction closes. Yeah, and 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, 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.

That's right. And then you mentioned that the lower 48 assets, or I guess the unconventional assets, are the lowest emission part of the portfolio, and the consular assets only add to that. I'm curious what the highest emission asset is, and is there any sort of, you know, getting at something in the international portfolio? Do you think about M&A in that regard as well, maybe those are more divester candidates that kind of accelerate the gold towards getting to your 2030 path?

Yeah, so the highest emissions assets in the portfolio, just now in the operated portfolio, it's really oil sands. That's why we're so focused on looking at ways to bring oil sands emissions down. And we've got a lot of aisles 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 the steam oil ratio that drives the emissions intensity. We're also going to be deploying more of these flow control devices. That brings the steam oil 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 come in at a 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 is 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 we bring that process together in what we call our marginal abatement cost curve. We have about 100 projects in there just now. Some of them are desktop exercises, feasibility studies. We're spending about $90 million this year between capital and operating costs on those projects. But we look across the whole asset base to try and find ways to bring that down.

And our targets, Josh, that we established 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.

Yeah, it's actually a good point, Ryan. It's mostly driven by the fact that 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 US and Canada. Like we're low up in Alaska, it's very low intensity as well. So the percentage of our production that's fairly 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 a...

And

we've

said that it's... 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 Reed from Wells Fargo. Please go ahead. Your line is open.

Hey, thank you and good morning.

Good morning, Roger.

I'd like to kick on really kind of a follow-up what you're talking about with Josh there. As you think about 21 capex

roughly

flat, and you said you have to be nimble next year for what comes, what would be the things you would be looking at? Presumably not simply oil price up down. I mean, I assume it's some macro factors, maybe help us kind of understand some of the signals you might look for for getting more optimistic in 21.

Yeah, I mean, it would be macro. We have to see how the demand responds to what looks like at the slower response than people were hoping for, especially with Europe and possibly the US 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 at the end of November and see when we get back to sort of drawing down the inventory. So the beauty of our position is that we've got incredible flexibility. We've got a low break even price to 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. That 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 break even and our balance sheet, we'll be in very good shape to assess that as we go through.

Okay. And I would add,

Roger, that... 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 the 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 in 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 you're right, there's a number of factors that we'll be putting into the mix as we look at not only 2021 plans, but what the next couple, three years look like as this business recovers back to a mid-cycle and whether it overshoots or undershoots.

Well, it's the oil industry, so it'll definitely do one or the other, 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?

Yeah, 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 our 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 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 Poncho, that we just think it's appropriate that we focus the exploration effort.

We manage those, Roger, to whether there's not excessive capital employed associated with those assets, but as Dominic said, we're going to do everything we can to monetize them as best we can.

And then 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, you know, US natural gas price has been pretty strong. And is there ability for Conoco to flex, you know, for that a little bit or is there, you know, where is your opportunity outside of associated gas or is that really the opportunity?

Yeah, 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, big marketer. So we were moving, you know, 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 just an absolute production side, we're not looking to ramp up, you know, dry gas. And it's mostly coming from the associated gas with the unconventional production.

Yeah, could you quantify some of the marketing, you know, benefits you all see?

Sure, I'd like Bill, he's head of our commercial organization to maybe provide a bit of color there.

Yeah, 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 services 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 across moving across pipelines. So we continue to look at that and continue to move and we're shipping gas for a profit. So, you know, up that 8 BCF a day, you know, 500 million cubic feet a day of it is ours, the rest of it's 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 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, you know, under a bit of a spotlight. So I'm just wondering if you guys have thought anywhere about that, any scenarios that you've run, outcomes that you might expect?

Yeah, sure. We've certainly taken a look at the various tax proposals out there, including the 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 particularly 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.

Yeah, 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 tidal 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, yourselves 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. Yeah, thank Doug. I'll maybe add a few comments. Matt can jump in as well. But yeah, 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're 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 a little bit today by duck inventory. But when the declines and the declines are hitting in and it was masked by tailman's coming back on, you know, there's going to be a drop in US 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.

Yeah, Doug, if I mean, I think you and I discussed this in the past, if you look at the our expectations for the exit rate for this year for US tight oil, it's somewhere between six and a half and seven million barrels a day. And they will be able to get a better calibration on that year as it approaches the end of the year. So that compares to over eight million barrels a day in December last year, 8.2. And to some extent that that drop flatters to deceive because people were still bringing wells on in the first quarter and into the second quarter. 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 to 21 and into 22. 21 will get a bit of a lift from the ducks. And but the people are going to live within cash flow, there's going to be a real challenge to see tight oil at seven 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 four million barrels a day less than the pre COVID trend.

And that's

just US tight oil. And we respond more quickly here because of the decline rates and the capital flexibility. But the similar issues are happening elsewhere. So although there is definitely uncertainty in how much the demand effect will be, it's likely to be less of a demand effect than the supply effect, certainly over the next few years. So to the premise of your question initially, you know, are we setting up for the bottom of a cycle here? Well, it certainly feels that way to us. And exactly when it turns will be dependent upon the demand and the COVID and how we'll go back to in the short term. But we're certainly setting up for a tight, tighter supply demand balance in a year or so, if not before that.

Yeah, so short, medium term, all about demand, medium, longer term, you know, supply starts to enter the picture as Matt described, and we have a couple of couple two, three scenarios around how we how we think what that slope and trajectory look like.

Thank you. Our next question comes from Paul Chang from Scotiabank. Please go ahead. Your line is open.

Hey, guys. Good morning. Morning, Paul. Why is that? Maybe it's a bit of a curve ball here. If we look at the trading and optimization or commercial operation, historically, that the US looking at that as a core center, mainly for facilitation, the European on the other hand, take a more aggressive approach and looking at it as a profit center. And they seem to be doing quite well and have a good logic to trade around your So from that standpoint, we'll conical 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 earning and the higher risk. So that's the first question. The second question with the last four arguments, say if you decide your longer term 10 year plan has changed due to different market conditions and that such that your future growth rate is going to be lower with the addition of the control 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.

Yeah, 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, yeah, we're looking at the commercial space and with the addition of a concho, you know, it is a, as you described, kind of a cost center inside the company. But you know, we're looking at expanding that, you know, as we think about the future and what the concho assets spring, 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 U.S. production that we would 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 assets, you know, again, I go back to our, it's a cost to supply primary criteria, but Matt can provide a bit more details about what might fall out.

Yeah, Paul, as you know, what we do is we try to optimize each of our individual, into the 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 the 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. Now there is flexibility across the portfolio and the pace. You can adjust the pace of any given project by a year or so. We can adjust the rate of which we increase the ramp and 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 honor our criteria, that wouldn't bust the criteria. The obvious places are lower 48 Alaska. That's where the flexibility mostly exists maybe in Canada as well. But I wouldn't really call it a specific asset. 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, then you're not maximizing the value that the diversification brings you. So we're trying to do is to make sure that we're running each of these assets at their optimal.

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

Good morning. Thanks for taking my questions. My first one is on ESG and the Paris Align climate risk strategy. And I think your commentary earlier answered a lot of what I'm looking for with the oil sand specific examples 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.

Yeah, thanks. It's Dominic here. I'll just take that. You know, recently I was pretty much involved in the low 48 and there's some really important progress we're making there. I think announced a couple of things here along with our new Paris Aligned strategy. One was commitment to zero routine flaring and that's the World Bank initiative there. So we 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 very reasonable cost. And we're able to now basically on our key sites we'll have this implemented. I think we'll have about 65 percent of our low 48 production covered by early next year. And this technology at very low cost allows us to sample the emissions around sites looking for methane 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 percent by 2030. And we really have first mover on this, as you'll know, Jeff. You know, we were the first U.S. based oil and gas company to set a GHG intensity target and we were the first U.S. based oil and gas company to commit to being power salined.

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

Thanks for the question. Two quick ones both regarding Europe. I guess it's 10 percent of your gas volumes. You know, no one is accustomed to seeing North Sea gas prices below three dollars in 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've seen with COVID related and demand related issues right now as we think about long term the macro supply around the world. We would see markets tend to 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 were 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 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.

Sonora, 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 Johnson from Capital One. Please go ahead. Your line is now open.

Hey guys, thanks. Just one question for me that 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. At today's share price, the paper loss on 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?

Yeah, 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 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 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, but continue to buy them through the low end of the cycle because that's what brings down the average cost to your shares obviously. So we still think it's going to be a piece of our return to shareholder pie. And the question begins, you know, 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 to 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 further questions at this time.

I'd

like to turn the call back over to Ellen. Thank you.

Great. Thanks, Inara. 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.