This conference call transcript was computer generated and almost certianly contains errors. This transcript is provided for information purposes only.EarningsCall, LLC makes no representation about the accuracy of the aforementioned transcript, and you are cautioned not to place undue reliance on the information provided by the transcript.
spk11: Good morning and welcome to the ConocoPhillips 4th quarter 2019 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 will 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 that this conference is being recorded. I will now turn the call over to Ms. Ellen DeSantis. Ellen you may begin.
spk13: Thanks Zanara. Hello to our listeners and welcome to today's call. With me in the room today are Ryan Lance our chairman and CEO, Don Wallette our EVP and chief financial officer, Matt Fox our EVP and chief operating officer, Bill Bullock our president of the Asia Pacific Middle East region and Michael Hatfield the president of our Alaska, Canada and Europe region. We are also with us today Dominic Macklin president of our lower 48 region was unable to join today's call. Page 2 of the presentation deck contains our cautionary statement. We will make some forward looking statements during this morning's call. Actual results could differ due to the factors described on this slide and also in our periodic filings with the SEC. We will 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 on our website. And with that I'm going to turn the call over to Ryan.
spk15: Thanks Ellen and welcome again to all our listeners. Well it's certainly early in the new year and the sector is already off to another volatile start. Volatility can certainly be tough on an industry or a company if you're not built for it. Well we're built for it with clear resilience to lower prices, full upside to higher prices and a shareholder friendly framework that works through the cycles. All of our usual results and outlook details can be found in today's published materials but we're going to keep our prepared remarks pretty short. Our main goal is to reinforce why Codico Phillips offers an attractive way to invest in this cyclical business. That's the key theme as we reflect on 2019 and we look forward to the future. 2019 capped off a successful three year period in which we transformed our business model and significantly improved the underlying performance drivers across our entire business. Slide three summarizes those 2019 results that contributed to this transformation. In the financial column we delivered strong earnings and we generated cash for operations of 11.7 billion delivering free cash flow of over 5 billion. Our balance sheet got stronger. We ended 2019 with over 8 billion of cash in short term investments and lowered our asset retirement obligation by almost 30% largely due to dispositions. And our North Star return on capital employed was 11%. We delivered on our volume projections for the year with roughly 5% underlying growth including 22% growth from the big three unconventionals. The rest of our portfolio delivered strong base performance and we progressed new projects and exploration opportunities across our regions. Our world class portfolio keeps getting better. As part of our high grading efforts we generated over 3 billion of disposition proceeds and we have another 2 billion of announced dispositions that we expect to close in early 2020. But we're not just selling. We're also on the lookout for opportunities to add low cost of supply resources to the portfolio like we did last year in the lower 48, Alaska and internationally. And when reserves closed for the year we replaced 117% of our production organically. 2019 was another outstanding year for delivering on our disciplined shareholder friendly strategy. We returned 43% of our CFO to our shareholders. That's essentially all of our free cash flow. We paid 1.5 billion in dividends including a 30% increase in our quarterly dividend and we repurchased 3.5 billion of shares. In today's announcement you saw our board approved an increase of our existing repurchase authorization by 10 billion to a total of 25 billion. This demonstrates our commitment to executing a consistent long term buyback program. Finally our execution focus goes beyond just the numbers. We continue to take leadership role in environmental, social and governance matters through target setting, engagement, disclosure, advocacy and stakeholder alignment. We call this performance with purpose and it's an imperative. So 2019 is over and we're in the starting gates for a new year and a new decade. In November we laid out a powerful 10 year plan that can deliver on all the elements we believe investors want from this sector. A disciplined strategy framework, consistent execution, strong free cash flow and compelling returns of and returns on capital. That's the path we set for ourselves in 2016. That's what we delivered in 2017, 18 and 19 and that's what we're ready to do again in 2020. We're focused on executing a strategy that we believe is right for the future of our industry and certainly right for ConocoPhillips and our investors. So with that let's go to your questions.
spk11: Thank you. We will now begin the question and answer session. If you have a question please press star then one on your touch tone phone. If you wish to be removed from the queue please press the pound sign or the hash key. If you're using a speaker phone 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 touch tone phone. And our first question comes from Doug Legate from Bank of America. Please go ahead your line is open.
spk06: Thank you. Good morning everybody. I appreciate the opportunity for a lengthy Q&A session so I've just got a couple and I'll let someone else jump on. I guess first of all there's a number of headlines have been circulating for quite a while now around Alaska tax and that's obviously a little different from the last time you presented to us back in November. So I'm just wondering if you can offer your perspectives as to how you think what you think is going on there and how you think that plays out whether they get signatures and what the implications could be as to how you respond to that. My second one is really on the production outlook for 2020. Obviously the Malaysia pipeline issue appears to be back on the table again so I'm just wondering if you could walk us through the cadence of how we should expect production to evolve through the year. I'll leave it there. Thank you.
spk03: Yeah thanks Doug. This is Michael. I'll answer the first question about the Alaska tax. So you asked where we are in this process. The Division of Elections in Alaska is currently certifying signatures now. They were gathered as part of the initiative for this November ballot. We anticipate that the initiative will be part of the ballot so they're in the process of certifying those now. Now as we showed in November, we're currently planning to invest about $25 billion of capital over the next 10 years in Alaska. These investments will increase the state's production and mitigate the current decline through TAPS. In fact, in 2020 alone, our net capital and OPEC spend in Alaska is expected to be roughly $3.4 billion. On a gross basis in 2020, total industry capital and OPEC spend in Alaska is expected to be about $6 billion. Now if there's a negative change in the fiscal regime, our investment plans will change. But we've been in Alaska for over 40 years. We know Alaskans understand the industry. It's the lifeblood of the state's economy. We believe Alaskans will understand that short-term revenue gain is a risky and fleeting proposition if it comes at the cost of billions of dollars of investment over the coming years. We've had ballot measure challenges over the past few years that would have negatively impacted our business and Alaska's economy. After understanding the issues, Alaska voters have voted no on all of them. Now we're part of an industry group that will provide information to voters about the benefits of the current fiscal regime, the benefits that it has on jobs, investment, oil production, and long-term revenue to the state. So the bottom line is we're working hard to ensure Alaskans understand the significant benefits that investment by this industry brings to the people and the state of Alaska under the current fiscal structure.
spk06: So as things stand right now, no change in your current plans, more of a -and-see type situation?
spk03: That's correct. In terms of our current plans, we're waiting to see. We're executing on our current plans, but we are gearing up to help Alaskans understand our view of the benefits that the current fiscal structure brings to the state and the people.
spk06: Okay. Thank you for that. On the production, Kenz?
spk04: Doug, this is Matt. I can give you an update on that. So the most significant update in our production guidance, as you mentioned, was associated with the KBB production in Malaysia. As you know, most of KBB's gas is sold through the third-party Sabah Sarawak pipeline to the Malaysia LNG plant, and it's exported from that plant. So in normal operating conditions for 2020, we would have anticipated about 20,000 barrels a day being exported through MLNG via the Sabah Sarawak pipeline. But right at the beginning of the year, there was a significant operational issue with the pipeline. So our expectation for the year, given that we don't operate that, is that that might not be repaired at all through the year. So that's what we're assuming at the moment. Now, we're hopeful that we might get access to some domestic gas offtake, but the magnitude of that and how long it might last is uncertain. So that's the vast majority of the adjustment to guidance. We also had some puts and takes across the business units. We also adjusted our expectation for timing of dispositions. But the new range of 1230 to 1270 are best guess at the moment of what we should expect for this year. And that's about a 4% growth on an underlying basis.
spk06: OK, Matt, I don't want to press the topic, but are there any particular dips in the quarterly cadence as we go through the year?
spk04: Well, obviously, we have turnarounds as we go into the middle of the year. We have one in the first quarter at Qatar, and then we have usual turnarounds in Alaska and elsewhere as we go through the second and third quarter. So it's a similar profile to previous years.
spk06: OK, thanks, everybody. Appreciate it.
spk11: Thank you. Our next question comes from Doug Terrason from Evercore ISI. Please go ahead. Your line is open.
spk10: Good morning, everybody. Morning, Doug. So, Ryan, you guys are one of the few, if not the only, big oil or E&P with higher rather than lower normalized returns on capital in recent years. And while your stock has been a top-five performer in S&P Energy three years in a row for this reason, in my view, your cash position is building. It's strong. You have better valuation in your equity than a lot of peers. And so you're basically better positioned than your peers for strategic activity. At the same time, you guys outlined a pretty compelling multi-year investment plan in November, which suggests that you can attain your returns profile even without meaningful strategic action. My question is, with the ongoing decline in upstream values that we've seen in public and private E&P, one, have strategic actions become more appealing to you guys? Are they more compelling? And what effect on return on capital employed is needed for you guys to move forward in this area? So two questions.
spk15: Well, thanks, Doug. Yeah, I think we believe we're on the right track with what we're doing in terms of what you describe. Our return profile focused on shareholder distributions, focused on free cash flow generation, and hyper-focused on our return on capital employed. As I said, 2019 was 11%. That is our guiding north star as we think about how we're executing the business. We have built a little bit of cash on the balance sheet. We believe we need it for the volatility we're experiencing in the marketplace. Just look at the month of January alone. Early in the month, I think people were thinking it was headed to $70 a barrel, and now people are thinking it might be going to $40 a barrel. So that's the kind of volatility we see in this business, and we're keeping a balance sheet so we can execute our consistent programs, pay our capital, pay fund the dividend, pay our buybacks back to our shareholders. So we're executing that consistent program. We believe in it. That's what we set up to do. That's what we described to everybody in November, that it's not just a one or two year plan. This is a plan that's got a lot of legs and can go on for the next decade. We have the portfolio and the people to execute on that plan. Now, we have been in the bolt-on acquisition game. We've had some assets that I described in my opening remarks, and we keep on the lookout for some of those kinds of opportunities. But we also, I think, laid out a pretty consistent framework at our analyst meeting in November about how we think about those kinds of opportunities.
spk02: As a consequence of that, we've resumed our legal enforcement actions. Of course, we're not the only creditor out there that's a competitive marketplace, and so I think you'll understand that I can't go into any details at all about what those enforcement actions entail. But as you saw from us in 2018, you can expect us to vigorously pursue all legal remedies that we have available to us.
spk07: We appreciate that. The follow-up question is just around some of the demand issues in Asia. I was hoping Matt and Ryan, you could put into context how we should be thinking about some of that demand weakness in the context of other demand shocks that you've seen, and just how does it affect the way you think about your business, if at all?
spk15: Yeah, and Neil, you're talking about demand for oil as opposed to, say, LNG?
spk07: Both would be interesting, actually.
spk15: Both, yeah. So we do see some, I mean, we're factoring in some demand loss in the first quarter of this year. And that translates into some reduction in demand as we go through the course of the full year. I think our estimate's still, as we look at the markets and look at the global economies, we're still projecting something on the order of 1 million barrels a day of demand growth as we go through 2020. Now, that's probably down 100,000 barrels or 1 to 200,000 barrels a day because of the current issues that we're facing with the coronavirus in China. So we do see some impact of that. It'll flow through to the storage side of the equation. So we'll see some building storage, we believe, in the U.S. and in the non-OPEC countries around the world as well. So that'll put, obviously, some pressure on prices. We see inventory draws, though, coming later in the year, and we still see pretty good supply growth in terms of total liquids coming out of the U.S. that probably eats up most of the demand growth that we see coming from around. So it's going to be another volatile year, and that's what we've been preaching for the last three to four years because it's a well-supplied world, and any small changes in demand or changes in what OPEC or others might do for the supply side will create that volatility that we've seen in spades here in January as well. We do see some weakness in the spot LNG market. It's had some pretty warm winters around the world, so demand has been – demand growth we still see over the long term in the LNG markets, but we've seen softness in the LNG side, and, of course, you know how that lags in terms of how it manifests itself in our cash flows for the company. So – but we still have long-term belief in the growth in the LNG market and still participating in that channel of the business.
spk07: All right, guys. Thank you.
spk11: Thank you. Our next question comes from Phil Gresh from JPMorgan. Please go ahead. Your line is open.
spk09: Hi. Yes. A couple quick questions. First, just looking at the quarter, in the lower 48, we saw some declines in the oil production. Quarter over quarter, NGLs and gas were up. I presume that was mostly mix effects in the big three with Bakken and Eagle furred down, but just any thoughts you could share around that as well as we look out to 2020 and your guidance for 410,000 barrels a day there. Just any color you could provide around rig count and production cadence specifically for the big three.
spk04: Thanks. Phil, it's Matt here. Yes, so I think you probably saw our numbers for the production individually for the big three. In aggregate, it was relatively flat. Eagle furred was down a little bit just because of the timing of when we were bringing wells on, and there was growth in the Permian. And the Permian production is a bit gassier than the Eagle furred production, that's why there was that slight mix shift. In terms of the activity, we averaged 12.5 rigs last year across the big three, seven in Eagle furred, three in Bakken and two and a half in the Permian. Those were supported by six fractures. You'll have seen in our capital that as we go into 2020, it's pretty much the same level of activity in aggregate to the same capital costs for the lower 40 years last year.
spk09: Okay, great. Second question for Don. The cash flows in the quarter looked a little bit light there. I think there was an other bucket that had some headwinds if you could just elaborate what might have been in that bucket and just generally how we think about cash flow for 2020 if there are any moving pieces we should think about, whether it's distributions or other things. You already talked about Petavesa, but anything else we should think about.
spk02: Thanks. Yeah, Phil, I can point to a few items that may help explain the cash flow in the quarter. The way we look at it, we take our rateable guidance items along with the cash flow sensitivities that we publish. If you do that and nothing else, you come up with an estimate of about 2.9 billion CFO. I think a lot of analysts came in at a number similar to that, whereas our actual results were about 2.7. To start, LNG realizations were about $100 million lower than what our sensitivities would have predicted because we don't incorporate the three-month lag to Brent pricing. Brent was up about a dollar quarter on quarter, but JCC fell $5. So that's what's causing that impact.
spk00: In addition to
spk02: that, our adjustable controllable costs for the year came in at $6.14 billion versus our guidance of $6.1. So that's $40 million or about $0.03 a share on that. And that came through the SG&A. And the items on – and you will have noticed that SG&A was up quarter on quarter, and what drove that increase was basically two things about equally split, -to-market on compensation because of the
spk15: good
spk02: quarter that the stock enjoyed in the fourth quarter. And the other was due to an accrual that was made related to employee-based incentive compensation. So those were kind of unusual items. And we also made a pension contribution to the U.S. qualified plan that was probably about $50 million higher than what our typical quarterly run rate was. And so I think if you look at those items – and even though we don't – we try to encourage people not to include the -to-visa $90 million payment, we know that some do. And so that may have been a contributing factor for some folks. As far as 2020, I think we've been pretty clear about what our distribution plans are, $3 billion of buybacks. Nothing's changed on that. Our dividend rate is what our dividend rate is until we consider adjusting it probably toward the end of the year, so that won't have much impact. As far as CFO, you've got some new sensitivities that have been updated for 2020 in the appendix of the materials that we published today. And I would say as far as a benchmark expectation on CFO at, say, current prices, around $50 WTI, we would expect about $8.5 to $9 billion of CFO.
spk09: Okay, great. That's very helpful. Just one clarification. With the proceeds from distributions, the $2 billion, I assume that's gross. Is there a net amount that you might have for that?
spk02: Thanks. I don't know that I can provide you a net on that. I know our Australia West headline number there is about 1.4, and we would expect cash proceeds to be about 1.1 based on our expectation of closing at the end of this quarter. And then Niobrara, the proceeds on that are going to be close to $400, about $380. But I haven't seen the estimates on cash on that, but I would expect it would be close to the proceeds. And then the remainder are just smaller assets that we'll do to round off to the $2 billion.
spk11: Thank you. Our next question comes from Roger Reed from Wells Fargo. Please go ahead. Your line is open.
spk12: Thank you. Good morning. And I think that was probably the shortest management introduction I've been on a call in at least the last several years. So congrats on that. A couple questions to follow up on. One on Neil's question about the demand issues in Asia, and maybe more specifically on LNG there. There have been some reports that some of the buyers in China may declare force majeure, and that's kind of a -in-time market. So I get that if they're not getting off-take, they're going to run into other issues. So I was curious, direct exposure to China as you think about it. And then the second question on the LNG front, just an update of where we are with the cutter expansion and everything.
spk16: Hi Roger, it's Bill Bullock. I'll take this one. First, we've heard some more concerns raised in the market about force majeure into Asia. But to date, we haven't had any force majeure declarations in Asia. So we are continuing to watch the market and see if we do, we'll be addressing those with spot sales or domestic sales in the market and managing appropriately. So nothing to date, but we have heard some more concerns. With respect to Qatar, we continue to be very interested in Qatar. We continue to believe we're well-placed. Qatar is a great location that serves the global market with low cost of supply resources and is a strategic location that works well for both Europe and Asia. We are still in the process. That process is being managed by Qatar Petroleum and they're in control of that pace. We're moving along at pace as they provide. I really can't say any more on that at this time. What I can say is that we're very hopeful the opportunity is going to be a competitive cost of supply addition to our portfolio. And as we laid out in November, it needs to be a competitive cost of supply to be an attractive addition. So that's kind of where we're at for Qatar.
spk12: Thanks. Just a quick follow up. Is there any reason to think anything material has changed in the project since kind of late last summer when it picked up and certainly the analyst day in November?
spk16: No. GP continues to manage a very good project.
spk12: Great. Thank you.
spk11: Thank you. Our next question comes from Janine Y. from Barclays. Please go ahead. Your line is open.
spk01: Hi. Good morning, everyone. My first question is on ROCE. Good morning. My first question is on ROCE. It was 11% very strong for 2019 and the 10-year plan calls for a 1% to 2% improvement per year, assuming you're a $50 WTI with some inflation. So ROCE about 16% in 2025. So in terms of what is contributing to this improvement, can you talk about the ROCE of the incremental addition, incremental production adds relative to what you're achieving today? So perhaps any color you may have on the absolute ROCE of the big three or maybe some future Alaska projects or any other conventional projects?
spk02: Yes, Janine. This is Don. I'll address the ROCE question. So yes, at the analyst day in November, we showed ROCE growing between 1% and 2% over the 10-year period and that's being driven primarily by production growth because we're working at $50 WTI real. So there's a little bit of contribution there. But the other thing that I would point to is our capital efficiency. Our DDNA is actually very flat while our production is going up. So I would point to those two being the primary drivers behind the improvement.
spk01: Okay. Thank you. That's very helpful. My second question is on Alaska and I think exploration. In the event that Alaska activity is either slowed or pushed further to the right for either regulatory reasons or otherwise, can you talk about what other opportunities may move into the activity queue as a result? I'm guessing these are mainly exploration activities because we assume that the big three and the motiny, all of those are already optimized for your 10-year plan.
spk04: Hi, Janina. Are you referring to what we would do in Alaska or what we would do elsewhere in the globe?
spk01: Elsewhere in the globe.
spk04: Yeah. So this year about half of our exploration capital is going into Alaska and half is going elsewhere. So the primary areas outside are a Norway exploration program that we discussed. Michael discussed that at the November analyst day. We also have an exploration program going on in Malaysia in the shallow water shelf of Sarawak. And we have exploration activity going on in Argentina, both in the south of the country and in the Waka Mwarta. Those are the primary new explorations activity outside Alaska.
spk01: Okay, great. Thank you very much.
spk15: I would add Janine that we set an allocation for exploration and if we don't have the opportunities to compete for the cost of supply that we set, we'd bring down that allocation. But today we're spending the $300 million on exploration that we've allocated to that channel.
spk01: Perfect. Thank you.
spk11: Thank you. Our next question comes from Paul Cheng from Scotiabank. Please go ahead. Your line is open.
spk08: Hi. Good morning, guys. I think the first question maybe is for Matt. Matt, in Permian, the fourth quarter, we see a big jump sequentially. Should we look at just the normal lumpiness because of the well coming on stream or that this is signaling a beginning of an accelerated development case and that we should assume the growth starting in this year will be accelerating compared to the last couple of years?
spk04: Yeah, thanks, Paul. Yeah, we did a very strong growth quarter on quarter in the Permian. It was about 23% growth. But that is, as you sort of implied, this real lumpiness as we bring on new pads there. So we actually expect Permian to be relatively flat in the first quarter and then growth will resume again through the rest of the year. We had an unusually lumpy fourth quarter production.
spk08: Matt, when do you think Permian will take on a more accelerated growth? When do you think you will have sufficient of the denination and the infrastructure in pace for that to happen?
spk04: Yeah, so what we laid out in November was we're running at about two and a half rig pace. We will build over the next few years to about six rigs running in the Permian. But that will be a sort of measured growth rate as we get the confidence, much like we did in the Eagleford and the Balkan and we're doing in the Montney. We make sure that we're, we've got the right spacing and stacking and completion design. So we're still in a bit of a learning mode there and we'll ramp up the rigs to the optimum over the next two or three years. So there is significant growth coming in the Permian, but it will be at a pace that's consistent with the pace of which we're learning how to optimize the completion and spacing and stacking.
spk08: Thank you, Matt. The second question is for, I think, Ryan. Ryan, over the last 12 months, ESG all of a sudden become a far more active topic among investors, even for the North American investor. And we have, over the last two or three years, we have seen some of the international integrated oil companies unite of that and move outside on making a lot of investment outside into oil and gas for the transitioning of the low carbon fuel transitioning or low carbon world transitioning. From Chronicle Phillips standpoint, I mean, how you guys look at that and say that with the transitioning in the low carbon world, are you going to essentially stick to what you guys are doing in the oil and gas or that you will be evaluating other opportunities set to supplement that?
spk15: Yeah, Paul, I guess right now we're focused on the E&P business. That's the kind of company we are, and that's what we're doing. We have a strong record on ESG in terms of transparency, how we think about that piece, how we manage the transition. We're focused on eliminating emissions from our operations. We've done that over 7 million tons over the last number of years. We're the only E&P company, I believe, that has an emissions target that is out there for our business. So we're focused on doing that when we get the external recognition for our climate stance, how we think about our climate action report, how we think about our sustainability report, and how we describe what we're doing in our business to make it a more sustainable oil and gas business. So yeah, we're focused on being low cost of supply and really taking care of our own in terms of our emission footprint and what we're doing in our activities to reduce our greenhouse gas emissions, flaring fugitive emissions, methane, all the above. That's what we're about. That's what we're trying to do, and that's how we're managing this aspect of the company.
spk11: Thank you. Our next question comes from Jeffrey Lambujan from Tudor Pickering Holt. Please go ahead. Your line is open.
spk14: Good morning. Thanks for taking my questions. My first one's on Alaska from an ops standpoint. As you continue helping to inform voters on the potential ramifications of the ballot measure, can you just give us a reminder of what operations over 2020 will focus on in Alaska and then any color on learnings from ongoing appraisal will be helpful as well?
spk03: Yeah. So as far as our base operations, we've got a big operation that we continue to execute both at Caparic and at Alpine. As Matt mentioned, we've got some smaller turnarounds that we've got to execute this year. We've also got the ERD rig that's going to be starting up in the second quarter in Alpine. So we've got a lot and we've got a lot of drilling that's going on. Now, in addition, you asked about our exploration program and we're in the middle of that now. So we've got four wells that we're going to drill at Willow, four appraisal wells and one flow test that we'll conduct. We spudded our first well at Willow at the end of January, so that's going on now. In addition, we're going to drill three exploration wells at Harpoon and we expect to spud the first well towards the end of February. So we'll be running two rigs between the Willow and Harpoon programs. Now, in addition, we have our NAR well opportunity that we spoke to you about in November where we had drilled the production well and we had tested that well and floated back through our central facilities. We produced up to 4,500 barrels a day from that production well and then that well was shut in as we monitored the pressure buildup. Since that time, we've also drilled an injection well that reached TD in early December. We flowed that well back to clean it up just recently and we're quite encouraged with those results. In fact, our peak flow back was around 2,500 barrels a day. That well's now being prepared for an injection interference test with the producer that I just mentioned. We're going to do an injection test and interference test to see how those two wells are talking to each other and that information is going to help us a lot as we optimize future development planning. So we're quite encouraged with the results that we've seen in NAR well. So in short, we've got a big program that we're executing across our assets in Alaska, including at the non-op asset in Prudhoe Bay.
spk14: Great. Thank you for the detail on that. My second question is just a follow-up to the discussion on how you all look at inorganic ads and the potential for those to come into the portfolio mix. As you look at potential opportunities and compare them to the existing asset base, what would you say are the disconnects between what you think could fit and what clearly doesn't? Are you seeing quality packages with just parameters on valuation? Is there a lack of availability of assets in areas where you look to potentially add exposure? And then lastly, are there any key differences between the domestic and international A&E markets as you guys look at the landscape today? Thanks.
spk04: Hi, Jeffrey. I think I'll take that. This is Matt. You saw that last year on the inorganic front, we did about $300 million of inorganic additions in the lower 48 Alaska and internationally. And we've laid out, and Ryan alluded to this a bit earlier, we've laid out very clear guidelines, we hope, and certainly clear internally as to what it would take in order to make an inorganic addition to the portfolio attractive. And we've said it has to have an all-in cost of supply, including the acquisition cost of below $50 a barrel, and it has to have a development cost below $40 a barrel to compete for capital. So we've been very clear on the criteria that we'd have to achieve. It's the same criteria for larger scale corporate activity and for our exploration program and for resource conversion within the portfolio. So as we look around the portfolio, we can see some potential for incremental bolt-ons, much like we did last year, but we're not at the stage of consummating any of those at the moment. But there are still opportunities out there that could be attractive additions to the portfolio as we go through time, as long as they meet those two criteria that I mentioned a minute ago.
spk11: Thank you. Our next question comes from Scott Hanold from RBC. Please go ahead, your line is open.
spk17: Thanks. I think this one's for Don. Can you discuss with the KBV pipeline down, how does that impact the financials? I mean, on a relative basis, how does that generate the cash flow relative to say the Conoco as a whole?
spk02: Yeah, Scott, for 2020, and as Matt said, we're not counting on the resumption of that Saba Sarawak gas pipeline. So the financial impact that we're estimating is about $90 million of cash flow and about $60 million on net income. And that's built into the sensitivities that we published this morning.
spk17: Okay, I appreciate that color. And turning really quickly back to Alaska again, how has the process or the progress going with evaluating a sell down in 2020 on that asset, considering obviously the propositions that are out there? Do you find it's going to be a little bit more challenging in front of the November ballot to get something done?
spk03: Yes, Scott. So I'll take you back just for a second to November at the analyst meeting when we provided our preliminary 2020 capital and production outlooks. And at that point, we reflected that we would retain our current ownership level through this year, so through 2020. And at this point, we only plan to sell down after the uncertainty related to the citizens initiative has been resolved. And after we fully interpreted the results of our 2020 exploration and appraisal program, and when we progress through Willow, through the concept select gate. So after we've satisfied those three criteria, that's when we plan to execute this sell down. So that pushes the sell down most likely well into the next year. We won't execute a sell down in a way that causes us to lose control of the investment pace. We're already confident that there's multiple quality parties that are interested in these great assets. We would be open to an value strategic transaction or a swap rather than cash if that makes sense. So that's where we are in the process. We're going to resolve some of these uncertainties and then we'll approach the market.
spk17: Okay, very clear.
spk11: Thanks. Thank you. Our next question comes from Joe from Baird. Please go ahead. Your line is open.
spk05: Thank you. On Libya is with the situation in Libya now is production basically zero at this point? And do you have any thoughts on the outlook? And I know you don't guide for production in Libya, but what are you assuming in terms of your cash flow? What production level are you assuming for your cash flow guidance?
spk03: Yeah, so you're right. We don't guide for production in Libya. Our guidance is excluding Libya right now because of the disruptions associated with this conflict. Our Libya project company and the Libya National Oil Company have declared force majeure and so we're just in the process of tapering down our production. We're not quite at zero now, but we expect to be fairly soon. So our hope is that these parties can resolve this conflict and we can restart operations soon, but right now we're tapering down towards not producing.
spk05: In terms of your cash flow guidance for this year, are you assuming that Libya is offline for an extended period or are you assuming kind of flattest production from the fourth quarter level?
spk03: Yeah, we're assuming that it'll just be offline then.
spk05: Okay, that's helpful. And on the defined benefit contribution, my understanding is that it was around $100 million in the fourth quarter and that you're guiding for about $100 million each quarter through 2020. So beyond 2020, should we assume the same kind of quarterly contribution or is this just kind of like a five quarter catch up? And could you talk about sort of the cash impact?
spk02: Yes, Joe, this is Don. Let me address that. So in the fourth quarter, our contribution to the U.S. plan was, I believe, close to $80 million. We probably rounded that up to $100 million. But we plan to continue contributions at that pace for the next three quarters, so quarter one, two, and three in 2020. And so what's occurring here is that we've implemented a liability management strategy that's intended to de-risk the pension liability over time. So the contributions that we make this year are going to allow us to shift more of our assets from equities into fixed income. And that's how we're going to be de-risking the plan and hopefully reduce contributions as we go forward. So after the third quarter, you should expect that our contributions will reduce significantly and then hopefully, depending on asset performance and interest rates, continue to be quite small as we go into 2021 and beyond.
spk05: Okay, that's very helpful. Thank you.
spk11: Thank you. We have no further questions at this time. I would like to turn the call back over to Ellen.
spk13: Thank you, everybody, and thank you again, Sinara. If you have any calls, please feel free to reach out to Investor Relations and look forward to seeing all of you over the next several months. Thank you.
spk11: Thank you. And thank you, ladies and gentlemen. This concludes today's conference. Thank you for participating. You may now disconnect.
Disclaimer