Good morning, ladies and gentlemen, and welcome to the Murphy Oil Corporation Second Quarter 2020 Earnings Conference Call. If at any time during the call you require assistance, please press star zero for the operator. I'd now like to turn the conference over to Kelly Whitley, Vice President, Investor Relations and Communications. Please go ahead.
Good morning, everyone, and thank you for joining us on our second quarter earnings call today. Joining us is Roger Jenkins, President and Chief Executive Officer, David Looney, Executive Vice President and Chief Financial Officer, and Eric Hambly, Executive Vice President, Operations. Please refer to the informational slides we have placed on the investor relations section of our website as you follow along with our webcast today. Throughout today's call, production numbers, reserves, and financial amounts are adjusted to exclude non-controlling interest in the Gulf of Mexico. Please keep in mind that some of the comments made during this call will be considered forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. As such, no assurances can be given that these events will occur or that the projections will be attained. A variety of factors may exist that cause these results to differ.
For further discussions of risk factors, see Murphy's 2019 annual report on Form 10-K on file with the SEC. Murphy takes no duty to publicly update or revise any forward-looking statements. I will now turn the call over to Roger Jenkins.
Thank you, Kelly. Good morning, everyone, and thanks for listening to our call today. On slide two, we look at where Murphy stands after the second quarter, and what a quarter it was. I'm sure we can all agree it was not typical, but our company swiftly took multiple actions to ensure that when we emerge from the downturn, we'll be a more resilient company. We rapidly reduced our capital spending for 2020 and amend our long-range plan. As we look to the longer term, we will deliver a flatter oil-weighted production profile with the goal of reducing debt, so we maintain our low leverage through future price cycles. Secondly, we work to right-size and realign our workforce and corporate structure to drive further organizational efficiencies. Operations teams continue to lower operating expenses, as well as drilling and completion wells faster and more efficiently, thereby achieving lower per-well cost.
Most of these savings are durable, which translate to enhanced margins along with free cash flow generation. Exploration programs in various stages in focused areas, providing significant upside to our existing resource base and optionality for future development. We continue to effectively manage COVID-19 risks by implementing work-from-home processes along with operational protocol. These processes and protocol have been highly effective in the office and field as we've safely delivered production within the current environment with zero impacts. I have to say, organization, that I could not be more proud of your resiliency and accomplishments over the last few months as we, like our peers, had to live with incredible uncertainty and stress that COVID-19 has created. We believe that an important tenet of Murphy's strategy is to maintain a multi-basin portfolio to provide flexibility and, in the long run, reduce risk.
Although we will not be providing formal guidance today, as we look toward next year, the flexibility we've built into our future business planning scenarios and our ongoing process of reducing costs will allow us to deliver on our goal of maintaining a conservative balance sheet with flatter production, paying our dividend, and paying down debt in an oil price recovery. On slide three, Murphy's second quarter production is 168,000 bbls equivalents per day, consisting of 58% oil and 65% liquids, and a near even division between our onshore and offshore assets. As previously disclosed on our first quarter earnings call, our production was negatively impacted primarily at 16,000 bbls equivalent per day that were shut in in the Gulf of Mexico due, as we know, extraordinary extreme low pricing.
We spent a total of $174 million in CapEx for the quarter, including $33 million for King's Quay, with CapEx totaling $542 million for the first half of the year as planned. Please keep in mind that we do expect, rather, to be reimbursed $177 million at the closing of King's Quay transaction, which includes $52 million spent in the first half of 2020. While oil prices experienced a black swan event, briefly falling to unimaginably negative levels, our realized price for the quarter was at $23 per barrel. Currently, we're seeing our various oil pricing points trade closer to WTI parity on a realized basis, which is our norm. Our overall natural gas price remained in line with previous quarters' realizations at $1.54 per Mcf. I now turn the call over to our CFO, David Looney, to give a financial update. David?
Thank you, Roger. Good morning, everyone. On slide four, like our peers, Murphy was substantially impacted by the historic low prices in the quarter. The result was a net loss of $317 million, or -$2.06 per diluted share for the quarter. Earnings were affected by several non-cash charges, all of which I am quoting here on an after-tax basis. An impairment of $16 million related to an expired offshore lease, restructuring expenses of $32 million related to our office closures in El Dorado and Calgary, and non-cash mark-to-market loss on crude oil derivatives and contingent consideration totaling $158 million. After backing out all these items, Murphy had an adjusted net loss of $110 million or -$0.71 per diluted share. Slide five. Due largely to the lower prices, our net cash provided by continuing operations was actually -$23 million for the quarter.
Included within this number was a $106 million cash outflow due to a working capital increase, which relates to our decreased level of activity. Combined with property additions and dry hole cost of $213 million, we had negative cash flow of $236 million in the quarter. For the first six months of the year, Murphy generated $369 million of cash from continuing operations with a $220 million free cash flow deficit after $589 million of property additions in dry hole costs.
Given that our capital spending was heavily weighted towards the first half of the year, with over 75% of total CapEx being spent in the first six months, the combination of positive free cash flow for the rest of the year, along with proceeds from the closing of the King's Quay transaction, should leave us in approximately the same liquidity position we had at the beginning of the year, which is a truly remarkable accomplishment given these difficult times for the industry. Through the team's efforts to reduce costs earlier this year, our LOE has improved to less than $9 per BOE. Excluding the $20 million Gulf of Mexico expense workover in the quarter, this falls even further to approximately $7 per BOE.
Lastly, Murphy has taken additional action to protect its 2021 cash flow with the addition of crude oil hedges of 15,000 bbls of oil per day for the year at an average price of $42.93 per barrel. Slide six. Murphy maintains a strong balance sheet with $1.4 billion available under our $1.6 billion senior unsecured credit facility, in addition to $146 million of cash and equivalents. Our next debt maturity isn't until mid-2022, with approximately 80% of our senior notes due in 2024 and thereafter. With the market shift earlier in the year, we opportunistically repurchased $19 million of senior notes with $12 million of cash in the first half of the year. Again, as Roger stated, Murphy's long-term goal is to reduce our total debt profile in an oil price recovery so that we have an even stronger balance sheet going forward. Slide seven.
Construction of the King's Quay floating production system, or FPS, continues to progress very well, along with our negotiations on the complex multi-party transaction documentation with ArcLight Capital Partners. The logistical effects of COVID-19 and extended stay-at-home mandates have caused delays in closing the transaction. Significant progress has been made on substantially all key agreements of late, and we're targeting closing in the third quarter of this year. As planned, the agreements include reimbursement of our previous capital outlays for the FPS, including $125 million in 2019 and approximately $52 million for the first half of this year. With that, I'll turn it back over to Roger.
Thank you, David. In slide nine, with the revised capital program and reduced onshore drilling schedule, Murphy will deliver free cash flow above our dividend this year based on current prices. We've prepared the company the past several years through oil-weighted development, accretive transactions, and appropriate balance sheet management. Our streamlined yet diversified portfolio provides flexibility through multiple avenues with additional value to our shareholders through exploration upside. On slide 10. We've reduced our CapEx by more than 50% from our original budget, with the midpoint of 2020 budget now at $700 million. As previously disclosed, reductions were made across our portfolio. We closed our corporate offices in El Dorado and have now relocated our headquarters to our existing Houston office. Additionally, we shut down our office in Calgary.
Both of these office closures, along with lowering staff levels in Houston, result in an overall staff reduction headcount of 30%. While a difficult decision, this flatter organization is better aligned with our business priorities going forward and results in ongoing cost savings beginning in the third quarter of 2020. As we enter the back half of the year, our greatly reduced capital plans, layered on with planned reimbursement from King's Quay and lower G&A expenses, will again result in cash flow in excess of CapEx with the quarterly dividend at current prices. Moving now to slide 12. In the Eagle Ford Shale, we produced 38,000 equivalent in the second quarter, consisting of 74% oil volumes. We brought on 11 wells as planned in our Karnes acreage. Murphy does not have any operated activity planned in the Eagle Ford Shale for the second half of the year.
In the Kaybob Duvernay on slide 13, we produced nearly 11,000 bbls equivalent per day in the second quarter, with 66% oil and 74% liquids. We continue to be very impressed with our Duvernay results in drilling and completion costs. Slide 14. Murphy reduced 237 million a day, no activity occurred after the first quarter. The asset will generate approximately $35 million free cash flow for the year, supported by fixed price forward sales contracts at the AECO hub for the remainder of 2020 and full year 2021. Slide 16. In our Gulf of Mexico business, we produced 72,000 bbls equivalent per day. It's comprised of 78% oil. As previously disclosed and discussed here, we were negatively impacted by shut-ins during the quarter, primarily at one facility. With workovers completed at Dalmatian DC-134 and Cascade 4, completed during the quarter for a total expense of some $20 million.
In addition, a second well in our Front Runner campaign was brought online. The third well was deferred as part of our capital reduction plan announced and discussed here. Several non-operated projects continue to advance, including the drilling of Kodiak during the second quarter, which is complete and is now awaiting a decision we made on the timing of the completion. On slide 17, in our major projects, we have Khaleesi, Mormont, Samurai, remain on track for first oil in mid 2022. Our team has been executing well over the project thus far and has remained within budget, with significant contract awards for key execution elements behind us. We're pleased to announce we signed our rig contract for a 10-well operation in this project starting in early 2021, which will allow us to progress our final permitting on the project.
Our operating partner spud the first producer well in the campaign at the St. Malo water flood project as well this quarter. Capital over the next three years for these major projects will average $260 million annually, ahead of achieving significant production in 2023, which is a key understanding of our projects and capital going forward, as we continue to support these major offshore projects through this down cycle this year. On slide 18, we're making progress on Block 15-1/05 in the Cuu Long Basin of Vietnam. We received final approval for the retainment area of the LDV field in the second quarter. We continue to mature remaining block prospectivity here and are awaiting submission for the field development plan for approval in the third quarter of this year. On exploration, slide 20.
As a non-op partner, Murphy participated in the Mount Ouray exploration well in the second quarter at a cost to us of $8 million. The well was a dry hole, unfortunately. In the third quarter, Murphy as a non-op partner will spud another opportunity called Highgarden in the Gulf of Mexico, targeting upper and middle Miocene targets. Total well cost again is estimated to be $8 million net our company. On slide 21, in other exploration, we maintain a significant optionality with diversified exploration portfolio, mainly focused on the Gulf of Mexico and the U.S., Mexico, Brazil, and Vietnam, all in various stages of evaluation. In our offshore Mexico blocks, a three-year discretionary Cholula appraisal program received regulatory approval, allowing us to drill up to three appraisal wells and complete all needed geologic and engineering studies.
Murphy's two non-operated positions in Brazil are moving forward, with partners agreeing to drilling prospects in the Sergipe-Alagoas Basin and seismic evaluation well underway in the Sergipe-Alagoas Basin. In Vietnam, our team has secured seismic data on 15-2, which is adjacent to our 15-1 block, as shown here, with the joint operating agreement nearing partner finalization. We're excited for the long-range plans we have in these areas and the opportunities they may bring us in offshore international developments ahead. On slide 23 at our future plans. Looking at the third quarter, we expect production in the range of 153,000 to 163,000 equivalents per day. Guidance is impacted by two major events.
We, in our planning, have an assumed storm downtime of nearly 5,000 bbls equivalent per day for the quarter, and we have repairs at our Delta House facility, leading to an additional 8,000 bbls equivalent per day of downtime there. We recently had a natural gas hydrate blockage in an export pipeline that occurred exiting our Delta House facility, which halted production. That has been remediated. However, we need to make some additional necessary repairs to the system, which will lead to further downtime this quarter. Further planned maintenance at our non-operated Habanero facility result in an additional 1,200 bbls a day of downtime. For the year, we plan to spend a range of $680-$720, as we discussed earlier this morning.
Should oil prices move material higher in the back half of the year, we have no intention to add to our capital, and we intend to build cash on the balance sheet and in turn allocate the free cash to reducing debt. As we begin the budgeting process for 2021, we plan to spend within cash flow, producing oil-weighted high-margin barrels, focusing on continued cost reduction, and delivering our longstanding dividend. We plan to give official guidance in early 2021. With that in mind, we believe with our capital program in line with 2020 spending, Murphy could deliver production volumes of approximately 150,000 to 160,000 equivalents per day on current pricing with our normal percentages of oil and liquids. Last slide, 24. I'd like to take a few minutes to leave you where we are at this time.
We're building a plan that emphasizes a flatter production profile going forward to support debt reduction in a price recovery. We continue to be laser-focused on costs in our company across all levels to improve our margins. We have a lineup of meaningful exploration opportunities over the next year, and we will build upside to our current resource base through targeted exploration. As always, we believe in protecting the health and safety of our workforce during the COVID-19 crisis. Maintaining a multi-basin portfolio for additional risk reduction and flexibility is a key for our company. On behalf of our executive team, I want to give my sincere appreciation to our employees, who are the driving force behind our company and culture despite the incredible uncertainty and stress of this time. Although we may not know the timing, one thing we can count on is the recovery in oil demand.
People around the globe rely on our products to make everyday life better, and Murphy intends to be there for that recovery. I'll now take your questions and awaiting that now. Thank you.
Thank you. Ladies and gentlemen, we will now begin the question and answer session. Should you have a question, simply press star followed by one on your touch-tone phone. You will hear a three-tone prompt acknowledging your request, and your questions will be pulled in the order they are received. If you're using a speakerphone, please lift your handset before pressing any keys. One moment for your first question. Your first question comes from Roger Read with Wells Fargo. Please go ahead.
Morning, Roger.
Yeah. Hey, good morning, Roger. How are you doing?
Good.
Quick question for you on the debt side. I appreciate you want to get debt down. I think that is a critical thing for the whole industry here. What would you describe as the right debt metrics for us to think about? At what point you would feel comfortable saying you could go to maybe 50% cash flow to CapEx, 50% to debt reduction, that sort of thing, just to maybe put a tighter framework on expectations there?
Well, at strip pricing, like most companies, it will take a few years to make advancements in our debt. What we're trying to do now, and the first thing you have to do, is stop borrowing and put money on your revolver. That's the first step, and that's what led to we had priorities to lower our capital and lower our cost structure and get that solidified around this mid-range of $700 million. That allows us to make it through the year, even with our dividend and with all this planned recovery from the King's Quay to allow us not to have any borrowing this year at these prices we have, which is positive. You got to maintain that going forward as a first step at strip prices from, let's say, a week ago, is a key part of our strategy.
We're looking and planning on a long-range plan now at this same range that I disclosed this morning, $150-$60. We're still working this, Roger. We want to take prices that are currently there and any advancement above that look to lowering down debt. If you're a person that believes in a recovery, we're going to keep this same level of spending and capital. Probably the midpoint of our capital, quite honestly, now at $700 million, is probably on the high end of our capital that we see in the next two to three years. Any kind of price recovery like that, once we get through these big projects, we have significant capital as opposed to this new, much lower capital as part of these projects, Roger.
As you know, that flow in 2023, but our significant long-term profiles of very high EBITDA for BOE at 23,000 a day for several years plateau, as shown in these slides. When we get beyond that period, we will have significant reductions in debt. We want to take this debt in a recovery down pretty low in the company. We haven't established those goals that you asked for yet, but we're trying to lower it way down. Get into a situation where in volatility like we had in this year, and these one-off events, that we get to keep our capital maintained with our liquidity and everything that we have, and not have to helter skelter our capital budget like that all the time.
That's something we've been working with our board on, a lot of meetings and a lot of discussion over the last four months.
Thanks for that. Within a program like that, would it be reasonable to presume you'll continue to hedge? Obviously this year, there were some opportunities on the hedging front, but I'm just curious, 2021, you think about the strip where it is, would you want to hedge much of 2021 as it comes in? Would you prefer to let's see a market recovery, which I think after the depths we've seen, better than strip would be, I think, most people's expectations for 2021 and 2022 on the crude price side.
Well, we're in pretty decent shape because in a recovery, we make so much EBITDA per barrel. If you look at any kind of data, we're going to be a leader in EBITDA and cash flow from operations from BOE. We do have a hedging plan. We're not going to disclose that plan this morning, but we have tranches. As David discussed a few minutes ago, we've marched our way up on that to 15,000 at around $44, $43. That we're kind of done at that level, and we're looking in a price recovery to hedge more. I wouldn't see Murphy over a 50,000-barrel-a-day kind of hedged company. We've not been a leader in that regard because we have the balance sheet and liquidity not to be a leader in that.
We have a game plan that's going up pretty aggressively from here, so I wouldn't anticipate a lot more hedging at the 43 level, Roger. We're walking our way up in stairsteps and may use a collar device as things get higher, which we haven't done before, and we're in the middle of planning out what to do about that. Our CFO team and our treasury team, of course, working on a hedging game plan. We have a plan right now, and it's going to need to walk up some more before we take any more off the table on that.
Okay. Great. Thank you for the clarity there. Good luck.
Thank you, Roger. Thank you.
Your next question comes from Gail Nicholson with Stephens. Please go ahead.
Morning, Gail.
Good morning, Roger. Looking at LOE, it was very impressive this quarter. Can you just talk about how we should think about LOE trending in the second half of 2020 as well as in 2021? What has been the biggest improvements that you have done on the LOE side to date?
Well, I look forward to not being any higher than this. We did have a real good quarter. Keep in mind that you have variable and fixed costs, as you know, We deliver these costs here even with a big field shut in for a good bit of production. I'm quite proud of that. You are seeing through the supply chain improvements in all types of services and rebidding and reevaluation of vendors. That's quite common. Of course, the vendors are doing that. We did one thing unique about our OpEx. What we call OpEx or LOE here, is we have had some very serious offshore completion, recompletion work that are operating expense that are one-off, These are well over 100% rate of return projects that strip.
When you turn a well on from 0 bbl to 5,000 bbls to 7,000 bbls a day in this environment, you make a lot of money still. At that 7 level, pretty low. I did real well on OpEx in Canada, bringing that down. Eagle Ford through the years, a lot of focus on chemicals and uptime and rod pumps and various levels of artificial lift. It's a goal of ours to keep this, got to be below nine, and it's our goal to do that, and I think we're going to be able to do that outside the workover situation.
Great. Then looking at the upcoming activity in the Gulf of Mexico, there's Calliope, Kodiak and Lucius that's going to be coming online in the fourth quarter 2021-
Right.
Fourth half of 2021 timeframe.
Right.
Can you talk about volume expectations for those wells?
Those wells, I'll let Eric talk about it. Let me frame this. He's going to tell you the volume expectations of those wells. Calliope is a well that's already drilled and completed and is tied back to a BP facility, and we've laid the umbilical and about to work on the pipeline. That's going to happen in the fourth quarter. Of course, with the risk of COVID and things, when can we get that tied up? Of course, we have that coming on late in the year. The other two projects are being, of course, non-op, and they're being planned to be executed by our partners at Oxy. We're partnered with Kosmos and others at Kodiak. I'll let Eric speak to the expectation there.
Yeah. The Calliope project is expected to come online in the middle of the fourth quarter. The initial rate contribution for the fourth quarter is in the 500, 600 net BOE per day range.
The IP would be what , Eric?
Quite a bit higher than that, like about 1,200 net BOE per day.
Okay, great. I just want to raise another one, if you don't mind. When you guys look at the major project spend that is remaining, you guys talked about $260 million on the annualized run rate. Can you just talk about how that major project spend has come in to date versus the original expectations? It seems to me that we're trending better than originally expected, but I just wanted to verify that.
Yeah. It's early days in that, and you hate to say go out and ahead of schedule. We've had some elements of the equipment and procurement that is below budget. We're happy with our rig rate was below budget. There's some gives and takes, and the subsea is down, and the rig rate is down to the original plan. Of course, we inherited a project and a capital that was ongoing. The facility, which is part of this King's Quay, we don't own it, but we're supervising the direction of the building. It's going very well. They have to mobilize that on a ship from Korea to the Gulf and bring it over here and take it offshore and set it up.
I'd say now that we're cautiously optimistic on being below sanction here with a couple of years to go, but I find ourselves very well-positioned in that regard. Then Gail, another key understanding about all this stuff about maintenance CapEx and what your CapEx's going to be, I think it's quite phenomenal actually, about we're laying out high levels of framing here this morning. Of course, we have two or three months to work with our budget with our board. If you start looking at a capital level on the lower end of our guidance we have this year, and keeping production in the mid-150s like that, you have to keep in mind that $270 million of that, let's say, $700 million is for projects that will not flow till 2023. Now, these are very high range projects.
They're way better than drilling the equivalent of $270 million of pads in onshore, I'll assure you that. Yeah, keep in mind, our maintenance CapEx to maintain production is really quite low and quite impressive. We're in our market cap compared a lot of times with peers that are just putting all their capital into onshore drill bit. We, of course, are not doing that, but it's a pretty low maintenance CapEx for the rest of the business if you pull out something that doesn't flow for three years. I think that's a key point to make this morning.
Absolutely. Just on that 150 to the 160 potential range in 2021, should we assume roughly oil composition is like 56%? Is that a good bogey?
That'd be a little higher than that.
Okay, great. Thank you.
Our goal is not to make it lower, so it'd be in that range for sure.
Your next question comes from Steve Dechert with KeyBanc. Please go ahead.
Hey, good morning.
Good morning, Steve.
Good morning. The 2021 outlook, is that based on a certain oil price?
All the work we're doing now is stripped from a couple of weeks ago and looking to use oil price recovery to help our balance sheet.
Okay, great. I just wanted to ask about Eagle Ford next year. Is there a plan in place to add activity currently or not really?
I'm sorry, I missed the first part of your question. Add what?
Is there a plan to add-
No. You're breaking up a little bit. That's okay. We're maintaining our capital. We do have some DUCs . We're not a big DUC outfit here at Murphy. Probably have about 12, 14 DUCs in the Eagle Ford. We'll be able to start the year off pretty well-positioned. In past years, we didn't really leave the year with many DUCs. That'd be our first big completion project. We'll start right after the holidays into early next year. We are not looking to add rigs or anything the rest of the year. We're going to ride out this CapEx range that we have in our disclosure this morning.
Okay. Nothing in 2021, though?
No. 2021, we're getting back into Eagle Ford again, for sure. Oh, yeah.
Okay.
We're going to start to maintain that Eagle Ford production. We have a certain CapEx to maintain that. No, sir. I thought you were asking this year. We don't have any more activity this year. 2021, part of that CapEx that we're disclosing this morning is, of course, related to Eagle Ford Shale.
Okay, great. Thanks
Eagle Ford Shale and our big projects is a big hump of that CapEx.
Okay. I appreciate it. Thank you.
Oh, no. Thank you.
Your next question comes from Betty Zhang with Scotiabank. Please go ahead.
Morning, Betty.
Hi, good morning. My question is on the Gulf of Mexico JV. It looked like the unit DD&A was quite a bit lower this quarter. Could you please explain the factors there, and if this is a good baseline going forward?
I'm sorry, what was that, ma'am, on the Did you say G&A?
The DD&A.
DD&A. Well, we had some impairments in the first quarter. You might recall something not too favorable here at Murphy, but we did have some impairments, which many of our peers did as well, and that lowered that DD&A there, Betty.
Okay, got it. My follow-up is on the Eagle Ford. On a longer-term basis, how are you thinking about running in the Eagle Ford?
We're really in the middle of our plans here now, and just had the last couple weeks of looking at that. I'm not disclosing that long term. We're trying to work in a 30K-35K a day range in there for $250 million a year CapEx kind of maintenance there. I think that's going to do pretty well and will lead to a lot of EBITDA and an oil price recovery if we flatten out our production there. That's what we're thinking on that, Betty.
Okay, that's great. Thank you.
No, thank you.
Ladies and gentlemen, as a reminder, should you have any questions, please press star 1. Your next question comes from Pavel Molchanov with Raymond James. Please go ahead.
Morning, Pavel. How you doing?
Good morning. Thanks for taking the question.
No problem.
We talked a lot about kind of the context of the oil market. I wanted to approach this from a slightly different angle. With six months into the pandemic, can you talk about how you have adapted on your offshore assets, specific kind of social distancing measures that you've taken in the Gulf to protect the workforce?
Really, thank you for asking that. That's rarely asked. I can't tell you how pleased I am and how proud I am of my offshore team. We were way ahead of this game with a really good crisis management team, real early in January, or kind of around January 28th. We were opportunistic there. We bought about 4,000 test kits and got these things procured and started testing every single person that goes offshore. Today, there's near 350 cases of COVID-19 in the offshore Gulf of Mexico off of facilities, platforms, and rigs. Murphy, knock on wood, has had one. This is unbelievable performance. We were ahead of the game. We didn't do just fever tests. We do these prick tests where you can get your blood and test it very quickly, screened a lot of people, really into all the distancing, all the cleaning.
Now this can change on you quickly. So far, we feel that we're a leader in the industry on it. As a matter of fact, we know we are, and we've done really well in that regard, and I'm super pleased about it. Our big thing is screening on the beach, and then, of course, the distancing and working offshore situation as well. Thank you for asking that.
Okay. A question about 2021. Total CapEx flat. How would you fund any kind of resumption of exploration in Vietnam, the Mexican portion of the Gulf, or anywhere else? Where would that be funded out of?
Well, that's in that capital that we're disclosing. It'd probably be next year in the high 60s to do the wells that we want. We're planning for a couple wells in Brazil, two wells in Mexico at this time, and one well in the Gulf.
Okay. 10% of the budget, roughly?
Yeah. It happens equal. That's fair. That's a good point. Yeah, I didn't think of it that way, but yes.
All right. Thanks very much.
No, thank you.
Mr. Jenkins, there are no further questions at this time. Please proceed.
Okay. Thanks, everyone, for calling in today. Appreciate it, and we'll look forward to seeing you at our next quarterly results meeting later this fall. Thank you.
Ladies and gentlemen, this concludes your conference call for today. We thank you for participating and ask that you please disconnect your lines. Have a great day.