Welcome to the APA Corporation Second Quarter 2021 Earnings Results Conference Call. At this time, all participants are in a listen only mode. After the speakers' presentation, there will be a question and answer session. Please be advised that today's conference is being recorded. I will now hand the conference over to Gary Clark, Vice President of Investor Relations, please go ahead.
Good morning and thank you for joining us on APA Corporation's 2nd Quarter 2021 Financial and Operational Results Conference Call. We will begin the call with an overview by CEO and President, John Christmann. Steve Riney, Executive Vice President and CFO, We'll then provide further color on our results and 2021 outlook. Tracy Henderson, Senior Vice President of Exploration Clay Bretches, Executive Vice President of Operations and Dave Purcell, Executive Vice President Development will also be available Our prepared remarks will be approximately 12 minutes in length and the remainder of the hour allotted for Q and A. In conjunction with yesterday's press release, I hope you've had the opportunity to review our 2nd quarter financial and operational supplement, which can be found on our Investor Relations website at investor.
Apacorp.com. Please note that we may discuss certain non GAAP financial measures. A reconciliation of the differences between these non GAAP financial measures and the most directly comparable GAAP financial measures Can be found in the supplemental information provided on our website. Consistent with previous reporting practices, Adjusted production numbers cited in today's call are adjusted to exclude non controlling interest in Egypt and Egypt tax barrels. And finally, I'd like to remind everyone that today's discussions will contain forward looking estimates and assumptions based on our current views and reasonable expectations.
However, a number of factors could cause actual results to differ materially from what we discuss today. A full And with that, I'll turn the call over to John.
Good morning and thank you for joining us today. In my prepared remarks, I will review APA Corporation's 2nd quarter results And comment on our outlook for the remainder of 2021. The company is making good progress on several key initiatives. We generated nearly $400,000,000 of free cash flow during the Q2 and at June 30, Held approximately $1,200,000,000 of cash, which will be used primarily for debt reduction. In May, we reached an agreement in principle with the Egyptian Ministry of Petroleum and Egyptian General Petroleum Corporation To modernize the terms of our production sharing contracts, the final draft of which has now been completed and will move to Egyptian Parliament For ratification in the fall and then to the President for his approval.
We are pleased with the progress thus far And believe that this modernization will return Egypt to the most attractive area for capital investment within our portfolio and will put Egyptian oil production back on a growth trajectory. In Suriname, as announced in our press release last week, We drilled a successful appraisal well in the Sapacara area, moving us closer to our goal of sanctioning the 1st commercial oil development. We are generating strong results from our DUC completion program in the Permian. And during the Q2, we closed 2 smaller scale Central Basin Platform Asset Sales as we continue to optimize our portfolio. On the ESG front, APA continues to deliver on our key initiatives and safety metrics.
Most notably, at the beginning of the year, we established an ambitious goal of eliminating routine flaring in the U. S. In 2021, and I am pleased to announce that we will achieve this goal in the Q3. This is the result of adding compression where appropriate, setting clear expectations and rules in the field and improving hydrocarbon processing at location. These efforts have also helped to drive down our flaring intensity, which is tracking well below our goal of less than 1% for the year.
Which is also well below our goal of less than 20% for the year. Turning now to operations. Total adjusted production exceeded our guidance in the 2nd quarter with the U. S. Benefiting from better than expected performance throughout our Permian Basin DUC Completion Program.
This more than offset lower international volumes where higher oil price impacted Egypt cost recovery volumes and we experienced extended operational downtime in the North Sea. Upstream capital investment was below our guidance for the quarter, primarily due to timing, while LOE was slightly above expectations. Our full year outlook for these items remains unchanged. In the U. S, we placed a total of 27 wells online in the Permian, including 5 at Alpine High.
In aggregate, these wells are significantly exceeding internal expectations driven by a combination Optimization initiatives. This effectively completes our backlog of Permian DUCs, so you will see fewer well connections during the second half of the year. You will also see Permian production come down a bit in the second half of the year as our current pace of drilling and completions Is not sufficient to offset the initial declines from the DUC completion program. As previously planned, we added a second Permian Basin rig in late June, which will enable a steadier pace of completions. In the East Texas Austin Chalk, we drilled 3 operated wells and are pleased with the results thus far.
We are evaluating the addition of a third drilling rig in the U. S. As previously noted, which would put us on a path To sustained oil production, given strong oil prices and the recent improvement in natural gas and NGL prices, All of our U. S. Asset areas are attractive candidates for this rig addition.
In Egypt, we have increased our rig count to 8 and continue to build high quality inventory across our expanded acreage footprint. Facilities expansion constrained our ability to connect Wells in the first half of the year and contributed to a decline in gross production during the Q2. As we wrap up our facilities work, well connections will increase Significantly in the second half of the year and gross production will begin trending up. In the North Sea, We continue to operate 1 floating rig and 1 platform rig crew. During the Q2, production was impacted by compressor downtime, Extended platform turnaround work and 3rd party pipeline outages.
Some of this carried over into July and when combined with planned maintenance turnarounds at Barrel will lead to only a modest production increase in the Q3. Once we conclude this heavy maintenance period, Production volumes in the North Sea should return to more normalized levels in the Q4. In Suriname's Block 58, we are running 2 rigs. Upon completion of drilling operations at Sapa Cara, the Maersk valiant will mobilize to the Bon Bonni exploration prospect Approximately 45 kilometers to the north, following Bon Boni, the valiant will return to flow test the Sapa Cara South-one well. Drilling activities continue at the Keskessi South 1 appraisal well with the Maersk developer.
On Block 53, where APA is the operator and 45% working interest owner, we recently signed a contract with Noble Corporation To secure a drillship that will commence exploration operations in the Q1 of 2022. Before turning the call over to Steve, I would like to comment on our outlook for the remainder of the year. Oil prices year to date This has created a very welcome amount of incremental free cash flow and will enable substantial progress on debt reduction this year. More importantly, our 2021 capital program will remain unchanged at $1,100,000,000 Even if we decide to add a 3rd rig in the U. S.
Later this year. In June, we opened our Houston and Midland offices And began welcoming back the majority of our office staff as permitted by regional guidelines. It has been great to see more in person collaboration In settings that we took for granted prior to COVID-nineteen and we will remain diligent with our protocols to keep employees safe. And with that, I will turn the call over to Steve Riney, who will provide additional details on the Q2 and our 2021 outlook.
Thank you, John. As noted in our news release issued yesterday, under Generally Accepted Accounting Principles, APA Corporation reported 2nd quarter 2021 consolidated net income of $316,000,000 or $0.82 per diluted common share. These results include items that are outside of core earnings, excluding the 2nd quarter impacts Of divestiture gains, movements in our tax valuation allowance, mark to market derivative losses and other smaller items, Adjusted net income was $266,000,000 or $0.70 per share. Most of our financial results were in line or better than guidance this quarter with just a few minor exceptions. As we've discussed in the past, we continuously review our portfolio for the right time to monetize assets that no longer compete for funding.
In the Q2, we closed the sales of 2 such packages in the Central Basin platform. These were mostly lower margin conventional waterflood assets, Which were producing roughly 2,500 barrels of oil per day. Proceeds from the sales were $178,000,000 As we look forward to the rest of 2021, we are updating some of our full year guidance items. We are effectively increasing U. S.
Production guidance by 4,500 BOEs per day and decreasing international adjusted production guidance By 14,500 BOEs per day compared to the midpoint of the previous respective ranges. This net decrease of 10,000 BOEs per day for the full year reflects the strong underlying performance of our U. S. Assets, But it also captures the impact of a few offsets. The unplanned operational downtime in the North Sea, The impact of higher oil prices on Egypt cost recovery barrels and the recent Permian Basin asset sales.
We are reducing full year DD and A guidance by $125,000,000 which reflects a combination of price related reserves additions And the impact of our changing production mix with lower North Sea volumes and higher U. S. Volumes. Finally, other than an increase to our expected U. K.
Tax expense due to strong commodity prices, there are no material changes to On a longer term perspective, one of our most important strategic goals is to return to investment grade status, which will require a significant reduction in debt. In the near term, progress towards this goal takes priority over the capital program, which today is still below a sustaining level of development capital. In other words, we are willing to under invest slightly in the short term to build balance sheet strength and financial resilience for the longer term. We entered 2021 anticipating a multiyear process of debt reduction. With this price environment, we're making significant progress more quickly than we thought possible.
In the first half of the year, At an average WTI price of $62 we delivered upstream only free cash flow, which excludes dividends received from Altus Midstream Of $860,000,000 assuming current strip prices for the second half of twenty twenty one, Upstream only free cash flow for the full year is expected to be around $1,700,000,000 The vast majority of this cash will be available for debt reduction. The rating agencies will ultimately decide when we return to investment grade, but we will clearly make significant progress in 2021. With meaningful progress on debt in sight, We would remind everyone that we have a strong portfolio of investable inventory and it would be prudent to at least increase Development capital to a production sustaining level. We estimate this would require around $1,200,000,000 of annual investment versus the $900,000,000 we are investing in development capital this year. At this investment pace And assuming prices remain flat with 2021, as we look out to the next several years, APA is capable of generating upstream only Free cash flow of $1,600,000,000 to $1,700,000,000 annually.
This is all based on our current portfolio of assets And to highlight what the current portfolio can deliver, this analysis assumes no further investment or future benefit from Suriname And no free cash flow uplift associated with Egypt modernization, which is still pending. And with that, I will turn the call over to the
Your first question comes from the line of Doug Leggate with Bank of America.
Thank you. Good morning. Good morning, everybody.
Good morning, Hug.
One for Steve and one for you, John, if that's okay. Steve, thank you, first of all, for Clarifying the more than $1,000,000,000 of free cash flow. That's much appreciated. The question I have is sustainability of that. The key thing for us is the value of the base business is How long you can sustain that cash flow?
You said for a significant amount of time. Can you put some parameters around that so we can kind of back into What the market isn't paying for? And I've got a follow-up, please.
Yes, Doug. And let me actually Put some parameters around the whole $1,600,000,000 to $1,700,000,000 of free cash flow That I talked about in my prepared remarks. And John said, it gets confusing because of the same numbers, but John talked about 2021 being $1,700,000,000 of free cash flow and that's based on first half actual prices plus the second half strip. And that is our internal most current outlook for the business for the full year. In 2022, we say $1,600,000,000 to $1,700,000,000 of free cash flow and that is sustainable for a run of years And we can talk about that a bit.
I'd put 2 caveats on that. Number 1, we're not attempting in any way to give guidance For 2022 and beyond at this point in time, that's a hypothetical case. But I want people to understand that that's a very We know our inventory today better than we've ever known it. And we've put together a realistic case Based on what we would actually invest in, in the current price environment. As I said in my remarks, it is focused on the current portfolio.
So We've kind of chosen to eliminate the noise associated with Suriname. It doesn't have any future Suriname CapEx, no future Suriname Production or free cash flow. And just to be clear, we don't want that to be to come across as any reflection on our feelings about Suriname because That doesn't reflect that at all. The prices that we used in that case are exactly the same as the 2021 prices, Because I didn't want those to affect comparability of the results. The CapEx, as we know, 2021 is 1,100,000,000 In our hypothetical case for 2022 and beyond, it's $1,200,000,000 There's a difference though.
The $1,100,000,000 includes $200,000,000 of exploration spend, which is mostly focused on Exploration and Appraisal, so there's only $900,000,000 of development capital in there. The $1,200,000,000 for 2022 Is all development capital. And we've talked about a number slightly lower than that $1,100,000,000 is sustaining capital Development or capital spending, that was when we were talking about sustaining oil production volume. The case that we put together now sustains the $1,200,000,000 sustains BOEs On a per day basis. So it actually is full production sustaining for a run of years.
That's adding capital to mostly to Egypt and to the U. S. Under this case, there's a slight decline in volume From 2021 to 2022 on an annualized basis, but then it's sustained from 2022 forward. So some people might be wondering, okay, you're spending $100,000,000 more of CapEx and you have a lower volume, but free cash flow is roughly the same From 2021 to 2022, how do you do that? First, there's debt pay down assumed in that.
So there's less Interest expense, because we are going to pay down somewhere in the neighborhood of $1,500,000,000 of debt, a little more than that, Including what was on the revolver at the beginning of the year. And then the other thing that people may not fully appreciate is The forward look, our production mix is changing. The spending will create a decline in gas volume and growth In oil volume, so again, prior case we talked about was a lower capital because it was just sustaining oil volume. This one is sustaining total volume, but growing oil relative to gas. And again, A reminder that doesn't include anything in there for Egypt PSC modernization, which is going to be meaningful.
The specific question that you had about the how long this is sustainable, if we want to get into the inventory, I'd let David Purcell will take that. I'll give him a chance to make a comment here quickly. But this is when I say for a run of years, I'll stick with the comment I made last time You asked me this question, Doug, and that is this is at least for 5 to 10 years that we can see out into the future. Dave, do you have anything to add?
I would just confirm that it's well beyond it's in that kind of 10 year window, Well beyond 5 years and once you get beyond 10, it's hard to think about anybody paying for that inventory. It has absolute sustainability to it.
Well, guys, thanks for the detailed answer. I really appreciate that, Because that's kind of what I was really trying to get to. I'm going to I love the tip of the hat that Egypt could be significant. I'm guessing you're not going to answer that question, so I'm going to go in soon, Andrew, if you don't mind. When you saw what we said about this, It seems to me that if you're 2.5 miles away with pretty much the same thickness on the formation and your oil target in South Acara, You're going to start to get some idea of the tank size.
I will let you know that we had a chance to speak with the Head of Stavasoli who talked about this as being Massive. So I wonder if you could just offer any thoughts on resource scale at this point and maybe A little bit of an explanation as to why not full test at that time, why do you have to come back to it and I'll leave it there. Thanks.
No, Doug, I appreciate the question. I mean, we are in the middle of the appraisal. And as we said, we have not flow tested Sopacar South. Unfortunately, just to clarify, the testing equipment on the Valiant is damaged And that's why otherwise we would we'd be flow testing that thing now. But it's going to take some time to repair that equipment and that's why The ship is going to sail on up to Bon Bonney and get on to the exploration well that we're excited about.
But we need flow tests there and we're in the middle of appraisal. We have not put out volumes yet. I mean, clearly, we're fine tuning things and working with things. And we've talked about this being an important Step towards potentially an FID, but it's just a little bit premature to get into areas and those Thanks until we gather a lot more data and we'll do that as we continue to appraise and analyze what we've collected. But we're clearly excited about it.
Having 30 meters of 1 blocky sand that's full base, high quality is the type of Saying that you can build around because you've got your H there, but there's a lot more to do here and a lot more appraise.
John, are we out for lunch on our tank model, 500,000,000 barrels?
Repeat that, but you cut out on me, Doug. I did not hear.
Sorry. Are we out for lunch on our tank order to suggest order magnitude with no oil water contact? You could be sitting on Half a 1000000000 bottles of nut prospect.
I'm just not going to comment at this point. We've got more appraisal. I appreciate The question and I'm going to stick to where we are. It's early. We're appraising and But we're clearly excited about it.
And but I'm not going to comment on your question there.
Can't blame me for driving. Thanks, fellas. Appreciate it.
Not at all.
Your next question comes from the line of John Freeman with Raymond James.
Good morning,
guys. Good morning, John.
The first question, I just wanted to clarify one thing on Egypt. So if you had the 5 rigs last quarter, you're now running 8 rigs. When we sort of think about The PSC being approved and obviously I've been vocal and again on this call about that would once it's approved that that's going to See an increase in activity. I'm just trying to make sure that I'm using the right baseline so that the incremental 5 rigs to 8 rigs. I know there was always some incremental activity planned in the second half, but is the 8 rigs the baseline that we're supposed to use ahead of PSC?
Or was there any Maybe additional rig or 2 that was added sort of in anticipation of the PSC being approved. Just want to make sure when I'm thinking about 2022 modeling But I'm using the right starting point.
Well, I mean, clearly, we're taking some steps that we've agreed with them. But in terms of your baselines for capital in those items, I think we're in the fairway to stay where we are. Dave, anything you want to add?
John, I think it's a good question. We've said, I think, hinted in the past that we think we need 8 to 9 rigs To keep oil production flat in Egypt, and I think you'll see the 8 rigs get us pretty close to that. And then we'll see what where we go after modernization. But I think John and Steve both talked about post Modernization could put us on a path to grow in Egypt. So if 8 rigs sustain that's a I think It's a pretty good baseline on your model.
Okay, great. And then just my follow-up and it's In conjunction, Steve, with the detailed response, you gave to Doug's question when sort of hypothetically thinking about 2022. So If I take what you just said on Egypt and the 8 rigs would already have sort of maintained levels and we'll just assume something North of that, so like Egypt post PSC would be growing. The North Sea I've previously talked about One rig, one platform can kind of maintain volumes at that $55,000 to $60,000 range. Obviously, first half of this year due to the extended maintenance, you're a good bit below that.
So just by default, the North Sea is going to be Up a decent bid in 2022 versus 2021. And then the Permian, it sounds likely the base case sounds like it would be To add the 3rd rig in the Permian at year end 2021, which gets that back to sort of a flattish sort of a sustained sort of profile. So Ex Cerna, am I just hypothetically thinking about those regions right?
Yes. I think directionally, John, that's about right. Most of the increased capital will be going to Egypt and a bit to the North Sea as I mean to the U. S. As well.
Probably not a whole lot of Additional capital in the North Sea, if any, but it will be better production in the North Sea simply because of the downtime that we've had this year, which Both planned and unplanned has been pretty material for 2nd and third quarter. But again, I'll just remind you John that this is a hypothetical case. We're not trying to give any type of guidance or rolling out Specific capital plans for 2022, that's still ahead of us for later this year. We'll talk about that some probably with 3rd quarter earnings.
No. Understood. Yes, the knucklehead almost like us that will be doing the speculating, but I appreciate all the answers guys.
Thank you, John.
Your next question comes from the line of Bob Brackett with Bernstein Research.
Good morning, all. Thanks for taking my question. I might be over interpreting this, but the fact that the Maersk developer is going to come back and appraise Keskezi South, does that mean that if you get a successful result on the well test, that's all the information you'll need On Sapacara to move it forward to FID or would you expect more appraisal wells there?
At this point, Bob, it Clearly needs to come back. We need a flow test, but I'll just say we still are appraising and we may need more appraisal. And so I wouldn't read into it anything more than that. Okay.
Just so there is multiple opportunities to move forward in the appraisal pipeline? Correct.
Okay. Thanks for that. You bet.
Your next question comes from the line of Michael Scialla with Stifel.
Good morning, everyone, and thank you for taking my question. This is actually Guillermo Stepanin for Mike. I was wondering if you could provide some additional color on the CBP asset sale. Do you foresee to monetize more non core assets like this one? And Are there any other assets in the U.
S. That you would want to increase your presence on?
I mean, I think we've always looked at the portfolio as That's kind of influx. We're always looking for things that make sense to monetize. I'd characterize what we sold as pretty high water cuts, Higher lifting costs, some properties we've had in the portfolio for quite some time and quite frankly it's time to move those Along the food chain, there's somebody else that will put more focus attention on them and quite frankly a little cheaper cost structure. But At this point, nothing major is planned. As always is the case, we like to report on these after we've done things, but we're constantly looking at a number of Thanks.
So but nothing major planned at this point.
That's helpful. Thank you. And my follow-up maybe on inflation. Are you seeing inflation in the drilling rates? You're planning to add that 3rd rig.
So I was just wondering if You would foresee a more expensive rate on that additional rig?
I think in general on the inflation side, we had a lot of our Key items secured for this year, I think you get into 2022 and we are seeing some uptick in things that are around the commodities, People, things like that, but I don't know anything particular Dave on rig contracts you want to comment on?
Yes. I think if you're looking for places For inflation, the completion side, pressure pumping and frac is where you'll see more inflation. We have that dialed into Anything that has to do with commodities, whether it's steel or on LOE With chemicals and diesel usage, you'll obviously see price inflation there. But for when we look at our forward plan, we think we have Adequately captured.
That's helpful. Thank you. That's it for me and congrats on the quarter.
Your next question comes from the line of Neal Dingmann with Truist.
Sorry about that. I was on mute. Hi, guys. Two quick ones if I could. First, just on Sort of capital allocation, how you're thinking about things.
My question is, I guess, once you obviously start ramping up in Egypt, is that going to simultaneously then Would that take capital away from the U. S. And others? Or I'm just wondering, could you talk about the thoughts about when that happens kind of how you View that activity versus what you're thinking domestically?
No. I mean, I think we've got a pretty good base run that we're running right now and that's where we've been. We've been pretty consistent. We did pick up the first rig 2 rigs early this year. We added the 2nd rig in the Permian.
We had a rig that drilled 4 wells In the Chalk in East Texas, in the U. S, but in North Sea has been pretty constant. Egypt, we've kind of moved from 5 or 6 rigs up to 8. In general, pretty level loaded, pretty constant, and I think it will be pretty consistent as building blocks going forward. You will post modernization see some changes to Egypt, but it will not impact cash flow or the Capital in the other areas in a negative way.
So
Okay. I assume that it's good to hear that John. And then just a follow-up for you Steve. To me, given what appears to be the strong transparency you continue to have with free cash flow, when do you all think about, I don't know, either call it notably or materially boosting dividends or free cash flow in addition to that your solid debt repayment program that you continue with?
I mean, I think the first priority is exactly that. We came in to this year with too much debt And we plan to pay debt down as Steve's made very clear. I think once we make progress there then you can start Think about the dividend, but the first priority has been the debt. And clearly, we're on a much faster pace there than we would have envisioned at the start of the year. But anything you want
to add Steve? No. Neil, I'd just say that when do we think about it? We think about that all the time. And We do realize it is a it's important and we need to do that.
And so I'm sure with the amount of debt pay down that We're certainly moving forward, not backwards.
That clearly is the same. Thank you. Thank you all.
Your next question comes from the line of Paul Cheng with Scotiabank.
Hi. Good morning, guys.
Good morning, Paul.
John, two quick questions. First, the second quarter effective tax rate on the adjusted Operating earnings seems low. Is there any one off items in there? Or what contributed to that Seems like less than 30% effective tax rate. Secondly, just curious, I mean, I think a lot of people will argue U.
S. Still have too many operators In the U. S. Shale, we don't need all the operators. So wondering that for Apache, Does it make sense that for you to try to
fund a
company with the nearby land position And from a vast scale joint venture and put everything together, everyone still has their equity ownership. So no one paying any equity premium to anyone. But that by doing it this way, you can drive much better efficiency and cost improvement than the individual need Perhaps that the company could be able to do. So is that something that you guys will entertain or you think that doesn't make sense for Apache? Yes.
I'll let Steve address the effective tax rate question first, And then I'll come back to your the second part.
Yes. Paul, if I think I understand the question Around the effective tax rate. What as you'll recall, We have put a 100% valuation allowance on the tax benefit of our Net operating loss carry forward in the U. S. On the balance sheet normally carry a deferred tax asset on the balance sheet And we've put a complete valuation allowance on that reducing that asset on the balance sheet to 0 even though we do have a pretty significant Tax net operating loss carry forward.
And what we do in periods of time like this in the Q2 when we have book income in the U. S. And we would normally recognize a tax expense. We release enough of that valuation allowance just To offset the tax expense for that quarter and you'll see that you'll see the $60,000,000 in our Non GAAP reconciliation from net income to adjusted earnings in that in the appendix in our supplement. So that will have the effect of lowering the effective tax rate quite a bit.
I see. So as long as that We have discussed commodity prices and U. S. Is earning a fair amount. We should assume the effective tax rate would be substantially lower And what say under more normal tax rate would suggest?
Correct.
Okay. We'll do. Thank you.
And Paul, your second question, it really just boils down to value. I mean, I think the nice thing about our assets, we've got high working interest. We now have 2 rigs operating in the Permian. I think it boils down to scale, efficiency and value added. And in some areas that could make a lot of sense, Summarize, it may not make sense, but we're open to looking at things as always the case.
Today, I think we like where we are. We like the pace. We like what we're doing. I think our wells are very competitive and the performance is very strong. And I think we're putting attention on the right assets within our portfolio today for us.
Got it. Thank you.
Your next question comes from the line of Gail Nicholson with Stephens.
Good morning. When you guys want to discuss about Alpine, with the Scenario that you laid out and keeping now equivalent volumes flat, is it fair to assume that Alpine potentially gets more capital in the 2022 forward timeframe? And how can you just talk about the 5 DUCs that you're completing and how those compare to previous wells?
Yes. I'll let Dave Touch on the DUC performance on those. And as Steve outlined Gail, it's holding VLEs Flat, but we actually are going to be growing oil and offsetting some of the gas. So in those cases, So I'll let Steve handle that and then Dave you can talk about the Alpine DUCs.
Yes, Gail. So just to be clear, again, we're not trying To say what exactly our capital program is going to be in 2022 and beyond, the hypothetical case that we used did not contain Funding of additional drilling in Alpine High, so it's more oil focused than gas focused, thus Gas volumes going down into the future, oil volumes going up. But we look at that all of the time Certainly with gas and NGL prices improving in the recent months and Could continue to improve. That'll be something that we will evaluate. And As we finish up this year and roll into next year, we'll get into the actual capital program for 2022, which very well could include some capital for Alpine High.
Yes. And Gail, on the performance, so we've completed 7 DUCs just to level set, 2 early in the program and 5 Kind of more in the meat of the program. The wells I think all the wells are Meaningfully outperforming our expectations and prior well results for offset wells That we would have completed in the 2019 timeframe. So very excited about the results. The last the most recent 5 still early.
They're producing, they've cleaned up and they're producing well, but we want to Continue to watch the performance curve before we spike the ball.
Great. And then just on the exploration front, there's a tremendous amount of potential on Ceramane, but you've also had success in other areas like the tertiary in the North Sea with Long span that you disclosed earlier this year. I was just wondering how you guys are thinking about exploration outside of Ceram over the next couple of years?
Yes. Tracy, I'll let you
Hi, Gail. I think we are very Excited about Suriname as you mentioned. And I think we'll be looking for other opportunities. I think we are in a very opportunity rich environment for exploration. So it's early days.
I've been with Apache now just right at 2 months. So you'll hear more about that as we go forward. Definitely, we'll be looking at other opportunities.
Great. Thanks, guys. An excellent quarter.
Thank you.
Your next question comes from the line of Leo Mariani with KeyBanc.
Hi, guys. Just wanted to follow-up
a little bit on Suriname here. You guys mentioned that you're in the process of Picking up a rig to drill a well. Apache operated on Block 53. Just wanted to kind of get a little bit more information about that. Is this kind of a mandatory well to hold the block?
Is this kind of a one off exploration well as you folks see it? And I guess is it just kind of a short term rig deal as a result? And what will be the rough capital net to Apache to go and execute that?
Yes. Leo, we've actually got one rig or one well required To continue to hold the block and so we've got to spread a well by June of next year and we're excited about that. I think there's a lot of Activity in Block 53, in terms of where you look at where the costs are going today, well costs are probably going to be Close to $100,000,000 would be my guess for gross. And we've got about 45% working interest in there. But I'll let Tracy talk a little bit about what we see exploration wise is we've got both Slope and more of a deepwater setting on Block 53 like we do at Block 58.
Yes. Leveraging on what John just said, we it's certainly not a one off exploration or seen as a mandatory well. I think what we've learned is An incredible amount with the exploration wells that we've drilled across 58. And the petroleum systems within the basin continues right into Block 53. So we're actually very excited and we see some prospectivity that's very analogous to what we've been drilling in Block 58 and what we've just seen with some of the recent appraisal wells.
I think we've learned a lot and those learnings will be leveraged into what we see in Block 53 because we do see very analogous systems.
Okay. That's helpful color. And I guess just given kind of the substantial plants that are existing in Block 58, which I is going to involve at least a couple of rigs every year for the next several years. And I know you have to get a well done by June, but Can you give us a sense of if you are successful here in Block 53, Is this kind of just another leg of the stool where this can kind of be a block that has concurrent activity over the next couple of years in parallel with Block 58? How do you think about the
Well, I mean the nice thing is we've got 2 partners here. We've got 45%. So I think it gives us a Optionality as we start to think about it. We are the operator of Block 53. We did do the joint venture and handed over operations in Block 58 to Total.
But I think it just builds out more optionality and more flexibility for us to look For different ways to continue to advance some longer term very meaningful programs.
Okay. That's helpful. And I guess just lastly on this potential for the 3rd rig that you've talked about here. Obviously, you decided to add some activity in Egypt. And I think you guys have strongly alluded to the fact that a 3rd rig can kind of show up in the Permian.
Trying to get a sense of what's kind of the decision point there? Is it really just about sustained higher commodity prices in the year end? And If that occurs, is that 3rd rig pretty much kind of coming for next year to try to hold BOEs flat with oil up and gas down a little?
No, we have not made a decision on a 3rd rig. I want to make it really clear. It's not in the budget this year. I think it's important because we've been under investing below sustaining levels to kind of articulate what it would take. And as Steve said in his prepared remarks, we're prioritizing debt pay down in the balance sheet first, Which is why we've been under investing, but the 3rd rig would be required to get to a sustaining level in the U.
S. And We've got pretty attractive options for that. So that's why that's framed that way. But it is not It's not a foregone conclusion that we're bringing it. We have not made that call and cap remain at the $1,100,000,000 for 2021.
Okay. Thanks.
Your next question comes from the line of Jeffrey Lambachan with Tudor, Pickering, Holt and Co.
Good morning, everyone. Thanks for taking my questions. My first one is just a follow-up on U. S. Upstream.
Obviously, throughout the first half PRU. S. Volumes have been more than offsetting the planned and unplanned international downtown, which you see more about in the full year guide as well even net of the CBP sales. So just Hoping you could talk more about what you've been seeing in non Alpine High Permian now that we're through the first half of the year and how that might influence capital allocation within non Alpine High Permian
Yes. Jeffrey, this is Dave. Good. Thanks for the question. We're seeing Meaningful uplift in our performance on the Permian DUCs outside of Alpine as well.
And it's We're optimizing on a number of different variables. We're excited about that program. And so when we I think Steve talked about it in his prepared remarks. When we look at our U. S.
Portfolio, we have multiple places where that could compete for the Capital for that 3rd rig and
that would
be the chalk. It could be in 3rd rig in the oily Permian and possibly The 3rd rig in Alpine. So we're evaluating those, but we're very excited about the performance that we've seen And the improvements that we continue
Got it. Thank you. And then second, just to try on the Egypt PSC modernization and understanding you can't speak to specific terms. Is there anything you can share at this time, maybe just on what mechanics are in flux that will help to increase capital allocation to that region?
No, I mean, I think you just got to look at it in terms of modernizing. It's we've got a lot of concessions, we'll be collapsing those, Merge and joint ventures, I mean, there's a lot to do there administratively that's going to make it easier and it will effectively keep us from trapping capital. But We're not in a position to elaborate more than that today. It's going through the approval process We should be in a position to talk about it later this year for sure.
Great. Thank you.
Your next question comes from the line of David Hickenen with Pickering Energy.
Good morning, guys. And Thanks for the hypothetical framework. It is helpful and we won't hold you to it for your budget. One of the things that we're curious about And on the gas side, have you all thought about joining any of the like oil and gas methane partnerships or certifying your natural Gas or moving in any of that direction to really quantify the improvements you're showing around emissions?
Yes. I think we're a member of One Future. I think what our approach has been to take real Tangible projects and steps that we can take. We're in the middle right now working on our sustainability report, which will be coming out Later in the year like we always do and we're monitoring all those things. I think the key for us is trying to focus on what are the material things we can Our business that are going to lower those emissions and drive performance, right?
And so those are the things we're focused on.
And as you think about your operations globally, would you move towards quantifying carbon equivalent emissions per barrel for The North Sea, Egypt or U. S. Operations?
Yes. I think what's we'll stay tuned and monitor Where things are going? I mean, for us, we recognize we've we need to continue to lower our footprint. We need to be in a position and continue to monitor and measure those and take those steps. And then we'll just Making the determining how what's the best way to show it and the best way to quantify it and also how to attack it.
In the end, it's about lowering emissions.
Okay. Thanks, guys.
At this time, there are no further questions. I'll turn the call back to John Christmann.
Thank you. So before ending today's call, I'd like to leave you with 3 points. The first two of which are important catalysts. First, we are very encouraged with the progress in Surname and look forward to having further results later this year. 2nd, the PSC modernization in Egypt will have an immediate positive impact for both the country and APA, And we are very pleased with how things are progressing.
Finally, the free cash flow capacity of our base business is robust and sustainable, And this will materialize in returns to investors. Thank you for participating in our call today. Operator, over to you.
Thank you. Ladies and gentlemen, that concludes today's conference call. You may now disconnect.