코드 에너지(CHRD) 2026년 3분기 실적 발표: FCF 4억 4,200만 달러 및 원유 가이던스 상향

코드 에너지(NASDAQ: CHRD)는 2026년 3분기에 약 4억 4,200만 달러의 조정 잉여현금흐름을 기록했으며, 이 중 대부분을 주주에게 환원했다고 발표했다. 경영진은 또한 견조한 기저 생산량과 운영 효율성에 힘입어 2026년 원유 생산량 전망치를 연중 두 번째로 상향 조정했다.

핵심 요약

• 3분기 조정 잉여현금흐름은 약 4억 4,200만 달러에 달했다. 주당 1.30달러의 기본 배당금 외에도 자사주 매입을 통해 주주 환원이 이뤄졌다.
• 2024년 에너플러스(Enerplus) 합병 발표 이후, 코드 에너지는 약 1,080만 주를 매입하여 완전 희석 기준 발행 주식 수를 17% 감축했다.
• 코드 에너지는 기저 생산 최적화와 실행력 개선을 바탕으로, 2026년 원유 생산량 가이던스를 초기 약 하루 15만 9,000배럴에서 16만 5,000배럴로 연중 두 번째 상향 조정했다.
• 최근 추진된 마케팅 조치를 통해 연간 3,500만~5,500만 달러의 비용 절감이 기대된다. 이전에 발표된 조치를 포함하면 연간 총 절감액은 약 8,500만 달러에 이른다.
• 코드 에너지는 분기 말까지 47개의 4마일 유정의 생산을 개시했다. 4마일 시추 비용은 1분기 대비 약 9% 감소한 반면, 수압파쇄 생산성은 연초 대비 20% 이상 향상되었다.
• 경영진은 레버리지 비율이 0.5배 미만으로 낮아진 후 잉여현금흐름의 최소 75%를 주주에게 환원한다는 목표를 계속 유지하고 있다.

주요 재무 데이터

사업 및 운영 실적

코드 에너지는 배컨(Bakken) 지역 내 최대 광구 보유자이자 생산 업체 위치를 유지하고 있다. 경영진은 회사가 현재 윌리스턴 분지(Williston Basin) 생산량의 약 13%~14%를 차지하고 있으며, 이 지역 내에서 자연스러운 통합 주도자 역할을 계속할 것으로 보고 있다고 밝혔다.

유정 최적화 및 화학 처리 프로그램에 힘입어 2026년 기저 생산량이 예상치를 웃돌았다. 코드 에너지는 산, 용제, 계면활성제 및 복합 응용 처리를 포함하여 생산 부문에서 수백 건의 처리를 수행했다. 회사는 2027년 프로그램에 포함하기 위해 어떤 처리가 최고의 수익률을 제공하는지 평가하고 있다.

4마일 수평 시추 프로그램은 경영진의 기대치를 지속적으로 충족했다. 코드 에너지는 분기 말까지 47개의 4마일 유정에서 생산을 개시했고, 완결된 모든 유정을 총 심도까지 세정했으며 유정 끝단(toe)을 통한 추적자(tracer) 회수를 확인했다. 경영진은 4번째 마일 구간의 온전한 기여도를 평가하기 위해 추가로 1년간의 생산 데이터가 필요할 수 있다고 언급했다.

운영 효율성 개선을 통해 한 자릿수 초·중반대의 비용 인플레이션을 상쇄했다. 4마일 시추 비용은 1분기 대비 약 9% 감소한 반면, 수압파쇄 생산성은 연초 대비 20% 이상 향상되었다. 작업팀은 현재 하루 평균 1마일 이상을 파쇄하고 있다.

비운영 자산은 코드 에너지 생산량의 약 10%~15%를 차지한다. 2026년 하반기 분지 내 시추기 활동이 약 30% 증가하면서 비운영 지출이 늘어났으며, 경영진은 이를 핵심 지역 내 매력적인 프로젝트에 참여한 것이라고 설명했다.

경영진 가이던스

경영진은 4분기 생산량 가이던스를 지난 8월 전망치보다 상향 조정했으며, 2026년 원유 생산량 가이던스가 두 차례 인상되었다고 밝혔다. 이러한 긍정적인 전망은 생산 최적화, 시추 및 완결 효율성, 그리고 추가적인 유정의 상업 생산 투입을 반영한 결과다.

코드 에너지의 수정된 2026년 자본 지출 전망치는 약 14억 6,000만 달러다. 이번 증액에는 직접 운영 및 비운영 활동 확대와 미드스트림 프로젝트를 위한 추가 2,000만 달러가 포함된다. 경영진은 미드스트림 지출이 점진적인 생산량 증가보다는 기존 운영 프로그램을 지원하기 위한 것이라고 설명했다.

2027년의 경우 경영진은 최종 자본 배분 결정 및 원자재 시장 상황에 따라 원유 생산량을 약 하루 16만 2,500배럴 수준으로 유지할 수 있는 가시성을 확보했다고 보고 있다. 구체적인 2027년 가이던스는 2월에 발표될 예정이다.

코드 에너지가 두 번째 수압파쇄 크루와의 계약을 해지함에 따라 생산량은 4분기에서 2027년 1분기로 넘어가며 감소할 것으로 예상된다. 12월은 4분기 전망치 중 생산량이 가장 적은 달이 될 것으로 보인다. 복귀하는 크루는 초기에 다중 유정 패드에서 작업할 예정이므로, 경영진은 2분기 전까지는 유의미한 생산량 증가를 기대하지 않고 있으며 이후 3분기에 추가적인 증가세가 나타날 것으로 전망하고 있다.

리스크 및 주시 사항

• 유가 변동성으로 인해 시추 투자와 자사주 매입 간의 균형이 달라질 수 있다.
• 2026년 서비스 비용은 한 자릿수 초·중반대 비율로 증가했다. 경영진은 2027년 전망이 원자재 가격과 업계 활동에 달려 있을 것이라고 밝혔다.
• 수압파쇄 크루 수급은 여전히 타이트하며, 두 번째 크루의 복귀 시점은 서비스 업체의 가용성에 달려 있다.
• 최근 발표된 마케팅 절감액 중 일부는 2027년 말 또는 2028년이 되어서야 실현될 예정이다.
• 코드 에너지의 연장된 수평정에서 4번째 마일 구간의 온전한 경제성을 확인하려면 추가적인 생산 이력이 필요하다.
• 코드 에너지가 연간 주기 전체에 걸쳐 직접 운영 프로그램을 조정할 수는 있지만, 증가한 비운영 활동은 연말에 유연성이 떨어진다.

애널리스트 Q&A 주요 내용

자본 환원: 경영진은 레버리지 비율이 0.5배 미만으로 낮아진 이후 잉여현금흐름의 최소 75%를 주주에게 환원한다는 방침을 재확인했다. 비핵심 자산인 마셀러스(Marcellus) 매각 계획은 거래 종결을 전제로 대차대조표에 추가적인 유연성을 제공할 것으로 기대된다.

배컨 전략: 마이클 루(Michael Lou) 신임 CEO는 코드 에너지의 전략이 여전히 윌리스턴 분지에 초점을 맞추고 있다고 밝혔다. 회사는 다른 지역의 기회도 검토하겠지만, 지난 5년간 완료된 5건의 인수는 모두 분지 내에서 이뤄졌으며 경영진은 이곳에서 코드 에너지가 가장 큰 운영 중복 및 시너지 잠재력을 보유하고 있다고 보고 있다.

마케팅 비용 절감: 3분기 실적과 함께 발표된 추가 절감액의 대부분은 2026년 또는 2027년 초에 효력을 발휘할 것으로 예상되며, 약 4분의 1은 2027년 말과 2028년에 반영될 예정이다. 이러한 효과는 집하, 처리 및 수송 비용, 원자재 실현 가격 전반에 나타날 것이며 임대 운영 비용(LOE)에도 일부 반영될 것이다.

헤징: 유가가 높을 때 헤지를 늘리고 낮을 때 줄이는 것이 코드 에너지의 방침이다. 경영진은 탄탄한 재무 상태 덕분에 광범위한 하방 보호의 필요성이 줄어든다고 설명했다.

잠재적 합작 투자: 경영진은 주주 수익률을 높이는 구조라면 고려하겠으나, 운영팀이 창출하는 뛰어난 경제성 덕분에 유정을 직접 시추하고 완결하는 것을 선호한다고 강조했다.

실적 발표 콘퍼런스콜 전문

전체 실적 발표 컨퍼런스 콜 녹취록

경영진 발표

Operator

Good morning, ladies and gentlemen, and welcome to the Chord Energy Third Quarter 2026 Earnings Conference Call. [Operator Instructions] This call is being recorded on Thursday, November 5, 2026.

I would now like to turn the conference over to Bob Bakanauskas, Vice President, Finance. Please go ahead.

Bob Bakanauskas

Thanks, Julie. Good morning, everyone. This is Bob Bakanauskas, and today, we're reporting our third quarter 2026 financial and operational results. We are delighted to have you on the call. I'm joined today by Michael Lou, our CEO; and Darrin Henke, our COO; Richard Robuck, our CFO; as well as other members of the team.

Please be advised that our remarks, including the answers to your questions, include statements that we believe to be forward-looking statements within the meaning of the Private Securities Litigation Reform Act. These forward-looking statements are subject to risks and uncertainties that could cause actual results to be materially different from those currently disclosed in our earnings releases and on our conference calls. Those risks include, among others, matters that we have described in our earnings releases as well as in our filings with the Securities and Exchange Commission, including our annual report on Form 10-K and our quarterly reports on Form 10-Q. We disclaim any obligation to update these forward-looking statements. During this conference call, we will make reference to non-GAAP measures, and reconciliations to the applicable GAAP measures can be found in our earnings releases and on our website. We may also reference our current investor presentation, which you can find on our website.

And with that, I'll turn the call over to our CEO, Michael Lou.

Michael Lou

Thanks, Bob. Good morning, everyone. Thank you for joining us. Last night, we issued our third quarter press release and presentation with details on our strategy, operations and financial performance. As this is my first earnings call as CEO, I'll start with a few thoughts on Chord's progress over the past several years and our priorities going forward. I'll then review our quarterly results and outlook before we open the call up for questions.

For more than 5 years, I've had the pleasure of working closely with Danny Brown to build a strong foundation for Chord. Danny is an incredible leader and a good friend, and I wish him all the best in his next adventure. Over the past 5 years, through volatile energy markets, the Chord team has strengthened our competitive position and delivered value for our shareholders. Today, Chord is a more resilient company positioned to withstand downturns and create value through the cycle. Continuous improvement has been central to that progress. Our talented team is committed to getting better every day and our results reflect that commitment.

As shown on Slide 9 in our presentation, we have grown free cash flow per share by roughly 35% over the past 2 years on a price-neutral basis, through disciplined capital allocation and driving operational excellence. Over a 5-year period, Chord has driven 11% annual growth in oil production per share. This growth has been delivered while we have built a large resilient production base with low declines, which translates to a low reinvestment rate and higher free cash flow generation. We have also preserved a deep low-cost inventory and improved its quality through optimized spacing, longer laterals, faster cycle times and disciplined acquisitions.

Over the past 5 years, we've completed 5 acquisitions in the Williston Basin, becoming the largest acreage holder and producer in the Bakken. These transactions varied in size and scope but we successfully integrated the assets and captured substantial efficiencies. We also streamlined our portfolio by divesting noncore assets at attractive valuations and reinvesting the proceeds in the areas of competitive strength. Together, these efforts have generated strong sustainable free cash flow, which alongside sizable share repurchases significantly increased production per share. We achieved this growth while returning substantial cash to shareholders through dividends and maintaining a strong balance sheet.

Looking ahead, our priorities remain consistent. We will apply the same capital discipline to organic investments and acquisitions. We will continue to improve performance across the business and evaluate every investment through the lens of shareholder returns. A strong balance sheet will underpin this approach, providing downside protection and the flexibility to pursue generated free cash flow above expectations and return substantial capital to shareholders.

We also advanced strategic initiatives that we believe will strengthen the business and enhance long-term free cash flow generation. Adjusted free cash flow was approximately $442 million, the majority of which we returned to shareholders. Beyond our base dividend of $1.30 per share, all capital return was through share repurchases.

Since announcing the Enerplus combination in 2024, we have reduced fully diluted shares outstanding by approximately 10.8 million shares or 17%. Said another way, we have repurchased over half of the equity issued for that transaction in a little over 2 years. Throughout 2026, the Chord team has driven wins across the organization. This leads us to a fourth quarter volume guidance that is well above both our August expectations and consensus estimates. We've also been seeing more favorable pricing, reflecting external factors and lower marketing fees.

We updated our capital outlook to reflect increased operated and nonoperated activity and an additional $20 million of investment in midstream projects. The operated activity is up a bit due to drilling and completion efficiencies, which are leading to a couple more TILs on the year and the nonoperated activity has picked up over the last few months as well.

Turning to continuous improvement initiatives. Chord has made further progress in reducing our marketing costs as the team continues to simplify and optimize contracts across oil, gas and water. Our latest efforts are expected to deliver $35 million to $55 million in annual savings. These savings are incremental to those announced a year ago, bringing the total annual savings to approximately $85 million.

On the production side, Chord continues to have success with a wide variety of projects aimed at optimizing its [indiscernible] in more out of the base, and that production continues to outperform. One of the things the team has been focused on and continues to test are various chemical treatments across a broad population of wells, and we expect to determine which treatments to incorporate into our 2027 program by early next year.

Our drilling and completions team continues to improve execution and set new records. We're making progress drilling more of our 4-mile wells in a single run while frac productivity is improving and cleanouts continue to reach total depth. As of quarter end, the company has tilled 47 total 4-mile wells. Execution and production results continue to be in line with expectations.

Slide 6 in our presentation shows the progress of all the continuous improvement projects across the company. The Chord team has delivered $225 million of incremental free cash flow generation over the past 2 years from controllable items, including higher production, better capital efficiency and improved marketing costs. Thank you to each person on the Chord team. This is an incredible team effort that has driven a ton of shareholder value.

So far in 2026, we have raised oil volume guidance twice, supported by strong execution and base production optimization. Looking ahead, we are confident in our ability to sustain strong production levels in 2027 and plan to provide detail of our next year's program in February.

Finally, we recently published Chord's 2025 sustainability report as part of our commitment to transparency. I want to thank the team for its work on the report, which highlights our efforts in emissions reduction, workforce, health and safety, corporate governance, philanthropy and other areas. We remain committed to producing affordable, reliable energy in a responsible and sustainable manner.

With that, I'll hand the call over to Julie for questions.

Operator

[Operator Instructions] Your first question comes from Josh Silverstein from UBS.

질의응답

Joshua Silverstein

Nice update on the operational front here. with the better base performance, longer laterals, the faster cycle times and going to more and more towards the 4-mile laterals now, you talk about maybe what the company's maintenance CapEx requirements look like? It seems like it's structurally coming a bit lower, especially with some of the other cost savings.

Michael Lou

Yes, Josh, thanks for the question. Clearly, the team has done an incredible job this year. You'll notice that we've increased guidance a couple of times this year on the oil side on production starting at $159 million, going to $165 million. A lot of that's kind of productivity and efficiencies kind of throughout the program. The base business has done a great job of outperforming on just every well that we currently have in the ground. On top of that, the 4-mile laterals has driven efficiencies. We've certainly seen a small amount of inflation this year that we've been able to counteract with continued efficiencies this year. So all that's been really positive.

You know that our capital programs kind of on a blended basis now, 146. So it's up a little bit because of the additional capital that we're spending a little bit on midstream with some of those opportunities coming around our efficiencies on D&C side that allows us to do a few more TILs on the operating side and a little bit more non-op. We've had about a 30% increase in rig count in the basin over the last -- the second half of this year. So we're certainly seeing some other operators picking up activity and we're participating in a little bit more on the non-op side.

So all that leads to capital now kind of at that $1.46 level. It's a little bit higher than where we were at the beginning of the year, but our production is up as well. So that's a good kind of level for this year.

Joshua Silverstein

Got it. And then just wanted to think about how you're balancing the free cash flow allocation, obviously, a very strong year for oil pricing. You highlighted the continuation of the buyback into the fourth quarter as well. Just given where the balance sheet is, should we still think about maybe a 75% of free cash flow going to shareholder returns? Do you want to build up some cash just in case oil prices continue to come lower? How are you thinking about that rate of return?

Michael Lou

Yes. Good question. On the capital allocation side, obviously, we've been -- I think we've had strong focus on that over the last 5 years, and we'll continue to have that going forward. And as you mentioned, we've got a lot of different levers that we can think about, whether it's this year, certainly, since the early part of this year with oil prices up, one of the things is sticking about are there short cycle kind of projects that we can bring forward volumes. You're seeing a lot of that in a lot of the base work that our team has done.

We've been able to do some good acquisitions. We've -- in that time frame that we've been bringing our -- even after the most recent acquisition late last year, brought our balance sheet back in under half a turn of leverage. So now we're back into that 75-plus percent of return going back to shareholders, so we'll continue to lean into that side. And then with a good sales of noncore assets in the Marcellus that should close later this year, we'll be in a great position no matter what the cycle brings. Obviously, we're seeing some volatility in oil prices over the last -- well here. But we think that we're going to continue to be in a constructive environment, and we're in great shape on that front.

Operator

Your next question comes from Scott Hanold from RBC.

Scott Hanold

Michael, congrats on the promotion. You've been with the Chord entity a long time. And you gave just some high-level thoughts on Core's future, but I'd be more interested to hear like strategically, do you see the business any different? And if you can layer in thoughts about like does it make sense for Chord to stay within the Bakken? Or longer term, do you see optionality of stepping out at any point in time?

Michael Lou

Yes, Scott, I don't think anything really changes from the way we've been messaging over the last few years. I think that we're the largest producer in the basin right now. We also have kind of a vast acreage position kind of across the basin. The nice thing for us is that we see for 13%, 14% of the basin today in terms of production. We've still got a lot of room to run to continue to consolidate the basin. We think there are some interesting opportunities that could present themselves over the next few years, and we want to be kind of make sure that we have a balance sheet that's ready for that, that -- we think there were probably the natural consolidator in the basin. We think that we can drive more efficiencies than anybody else. We have more overlap than anybody else in a number of these positions.

So we think that there's just like a lot of opportunities in front of us in the basin. We'll always look at things outside the basin, but we've been doing that for 5 years and if you look at kind of track record, we've done 5 deals and they've all been within the Williston. That's where we can -- we know what we can drive in terms of value. So I don't think the change will be any different. In the meantime, our focus continues to be on what we have in front of us. And we talked about that continuous improvement side. And we've got to get better every day on our asset. And that would -- as we do that, it gives us more of the right to be the consolidator in the basin going forward. So there's going to be a continued focus on just getting better every day and that continuous improvement side.

Scott Hanold

Appreciate that. My follow-up question is a little bit on 2027. I know you're going to give guidance next year. So I won't kind of pin you down to that or anything like this. But your base production has improved quite a bit this year. It looks like at least 3,000 barrels a day. As you kind of think of the current environment we're in, and your prior view of 159 being sort of that baseline level for you all. How do you think about that base improvement? Should we add that to the prior 159. Is that how we should think about it? Or is -- does that provide you an opportunity to flex down in case something on the macro side becomes uncertain?

Michael Lou

Yes. I think we'll always look at what the right thing to do is on that capital allocation side. And obviously, if our shares, we think, are in a great place to buy back right now. But if you saw massive weakness in oil price and capital costs don't come down and the same proportion? And should we allocate more to buybacks? Or should we allocate more to the drill bit, we'll make all those decisions going forward. Right now, we think there's good visibility on some of those production improvements, and we see good visibility on kind of holding that new call it, 162.5 flat going forward. So that's, I think, what we're looking for next year. But we're seeing that base performance really been replicated longer term.

Operator

Your next question comes from Gabe Daoud from Truist.

Gabe Daoud

congrats on the promotion. I was hoping we can maybe yes, sure -- I hope we can maybe start with the marketing. -- upside that you guys have articulated through some renegotiations. I guess curious if you could maybe frame where -- what the realized run rate is today and how much additional benefit maybe kicks in next year? And what drives the ramp towards like that high-end number that you guys highlighted?

Richard Robuck

Sure. Yes, that's a great question. I think we've been talking for some time -- this is Richard -- for some time now about the fact that this organization was put together over the past 1.5 decades with a bunch of consolidation in the basin, where there's small players that have come together and then we brought together obviously, the kind of the 3 largest companies in the basin. And over time, each one of those organizations are putting in marketing contracts, most of those got put in place in the early 2010s through '15, and there were kind of 10- to 10-year deals. And then over time, they start to expire. And with the consolidation, you just have a lot more flexibility one, to pivot around with your rigs to pick and choose the best places to drill from a rock perspective as well as a marketing economics perspective.

And then two, you have the ability to put together and optimize around the contracts that you do have. And that whole while as we were consolidating the basin a lot more midstream infrastructure was being put in place and being built by all the different midstream folks that you know well that are playing in the basin. And so with our efforts with the starting contracts and then just the consolidation we've done, we've had a ton of success. We announced the incremental uptick today. that -- the way we've articulated that is like on an annualized run rate basis. So a fair amount of what we announced on an incremental basis today is going to be worked through this year or early next year. And then there's probably a 1/4 of it that's still to come in the late '27 and '28 time frame.

So there's still stuff that we have put into place that won't occur until a little bit out in time. But it's -- the team has done -- the marketing team has done an amazing job optimize on that front. And we still see that there's room to go from the perspective that there's still contracts that are coming due and the team is trying to optimize around that.

Gabe Daoud

Okay. A quick follow-up to that, so most of it lands in the GP&T line item. Is that fair? So there's maybe more downward pressure on the $260 million?

Richard Robuck

Yes. I mean a piece of it is there, obviously. I don't -- I'm not trying to be okay, but it is there, but you also see it in realizations as well on the NGLs and gas side. So that's a component of it. You'll see it in the GBT. And then to a lesser extent, you'll see it on the LOE side. as we work on the water contracts as well.

Gabe Daoud

Got it. Okay. No, I understand, just given the contract structure it can land in different buckets, but that's helpful. And then my follow-up guys is just maybe an update on your 4-mile lateral program. You noted Fort 7 have been till to date. Just any maybe updated learnings on the productivity side? Is it still more or less tracking how you thought the wells would do relative to 2 milers?

Darrin Henke

Yes, Gabe, this is Darrin. Yes, the 4-mile wells are performing right like we'd expect. We're drilling them a little bit quicker than what we were earlier in the year. Our drilling costs are down about 9% since the first quarter. And the production performance is as expected at this point. We're probably a year away from really figuring out what's the full contribution on that last mile, that fourth mile. But to date, all of our tracers are showing recovery clear to the toe. We've cleaned out every single 1 of our 4-mile wells to the toe. And everything is -- the team is just performing flawlessly. So no surprises there at this point.

Operator

Your next question comes from Kevin MacCurdy from Pickering Energy Partners.

Kevin MacCurdy

Congratulations, Michael. My first question on the non-op. Maybe you can give a little bit more color on the size of the non-op increase? And are there indications that that's going to kind of persist into 2027?

Michael Lou

Yes. I mean, think about this, we had about a 30% increase in rig count towards the second half of the year. a lot of other operators with the higher oil prices picking up rig activity. And so what it's doing is it's driving some of that late in year non-op activity that's driving that. With a healthy oil price. So I would assume that some of that stays into next year. Obviously, we can through a full year program, we can flex a little bit with our operated program to kind of manage that. But some of this late in year stuff is a little bit more difficult to manage. But they're good projects, right? I mean we're in a constructive oil price. This is in areas that are good areas that we want to participate, the good returning projects. So we'll participate here at the end of the year. That's a little bit of that color.

Kevin MacCurdy

Great. I appreciate that. That's helpful. And then as a follow-up, and I don't want to get too cute on forward guidance, but does the additional CapEx that you're spending in fourth quarter and maybe those -- the 2 new turn lines and the non-op, does that help the kind of decline that we've seen in the first quarter over the past couple of years at Chord, maybe kind of keeping your production more level loaded?

Michael Lou

Yes. I think that's a great question. But the reality is we dropped that second frac crew and so we've been coming down. So like our entry to exit, if you will, for even the fourth quarter as, I'd say, higher to lower. So December is going to be the lowest month of our fourth quarter guide, and that's going to trail into the first quarter as well. And then we'll start the frac crew. But we're doing primal fracs and multi-well pads. And so you really won't see I would say, like the pickup until the second quarter. So like in the past, you'll see 1Q dip and then will start to climb in the second -- in third quarter. And that's a typical program the way that we've been laying out over the last few years.

Operator

Your next question comes from Bert Donnes from William Blair.

Bertrand Donnes

Congrats, Michael. Looking forward to seeing what you do with the assets. And then on the pull forward of CapEx on the midstream side, I just want to make sure I understood. I think I heard it described as kind of supporting next year's program. But then obviously, you guys are holding flat for now at least. Is that -- was that spend to support the flat program? Or does that set you up for potential growth next year?

Michael Lou

Yes, that midstream capital is think about what Richard was talking about in terms of work with other midstream guys, we've got contracts that are coming up and we can blend and extend, we can renegotiate. We can go with new providers. We can -- there's a lot of different things we can do in areas that we feel like we're not getting the best rates we can do some of that ourselves as well. What we found is that there's some of these areas where we're doing some of that ourselves. And it's just a little bit higher as we think about stuff that we're setting up for '27. So that's just to support the current program.

Bertrand Donnes

Got it. So it sounds like it was going to happen anyway, you're just moving where the capital is coming from. Is that right?

Michael Lou

Yes. I mean some of this can happen or if you get good third-party rates like we're happy to go with third parties, too. So it's just -- some of it is just opportunistic based on what we're seeing in the market and whether or not we're getting kind of aggressive fair rates from others or if we should do some of that ourselves.

Bertrand Donnes

Got it. Makes sense. And then kind of around M&A, but not directly. It's our understanding that their Chord isn't the only company that's maybe looking to make an acquisition or expand in the Bakken -- is there any interest because you have 10 years of inventory that may be pulling in a JV or a carry and maybe have your CapEx budget unchanged, but have someone else kind of foot the bill for that tail end inventory at the end of your stack.

Michael Lou

Yes. Good question. I mean it's always about capital allocation. So if we find good ways to think about getting better returns for our shareholders, we'll consider everything or we look at all sorts of stuff all the time.

Richard Robuck

I think it's also fair to say when you look at the best operators in the basin, we would say we are the best operator. So I think we really like to drill and complete our own wells because of the strong economics that we deliver. But there are times on a PV basis, you might think about it differently, but that's definitely a consideration on how good the team is doing here. .

Operator

Your next question comes from Noah Hungness from Wells Fargo.

Noah Hungness

Michael, congrats from the new role. For my first question here, I had one of the past on just well cost inflation, just how you're seeing leading well costs, for your 2, 3 and 4 milers, what are they now? And how has the cycle plans kind of offset some of that inflation?

Darrin Henke

Yes. So -- this is Darren. Year-to-date, we've seen kind of low to mid-single-digit type of inflation and due to the team's performance, we've been able to offset that with efficiency gains. So -- as far as specific drill times, I mentioned earlier that we have reduced our drilling costs on our 4-mile wells about 9% since the first quarter. And our frac efficiency year-to-date as far as when you think about how many feet per day that we are fracking, that's gone up over 20% year-to-date as well. So we're actually fracking over a mile a day on average at this current time. So definitely seeing inflation, but the team has done a great job offsetting it with efficiencies and depends upon the commodity price environment next year and what environment we're in, but our teams have done a great job historically of offsetting inflation with efficiency and I wouldn't expect anything different at this time looking forward.

Noah Hungness

That's helpful. And then my second question is a bit of a clarification question around the second frac or that you guys spoke about that could come back. And late '26 or early '27. Could you just maybe talk about what would drive it to come back earlier rather than later?

Darrin Henke

Really just a function of availability, the frac crews are tight in our industry, and we've contracted that crew. It's been awarded, and it's really just working with that service provider on their timing and availability relative to the work that they already have scheduled through the -- roughly through the end of the year. .

Noah Hungness

And if it does come back in late '26, does that impact the til comp that you guys provided on Slide 23? Or would the to still be '27 story?

Darrin Henke

Yes. I would think about that in terms of frac has a lot of work to do before you bring it online. So it's not going to change that piece of the business. .

Operator

Your next question comes from Oliver Huang from TPH.

Oliver Wong

Just a quick one on hedge velocity [indiscernible] .

Darrin Henke

Sorry, Oliver, you're kind of breaking up here. If you try to repeat the question, otherwise, we have to pick it up offline. You kind of broke up there. Could you try to repeat it? .

Oliver Wong

[indiscernible] .

Richard Robuck

Yes. Oliver, this is Richard. We are struggling to hear you. My hope is that everybody else can hear us, and so I'm going to proceed along those lines. And you can follow up with your question, if I did not address it. to what you were looking for. But generally, we've had the same hedge philosophy over the past few years, which is when oil price is higher hedge more and when oil price is lower, hedge less. And then over -- in the near term, we're going to hedge a little bit more. And then over time, we're going to hedge a little bit less. And so obviously, with the strength of the balance sheet that we have, we don't have a need to protect the way that others might need to protect if they have higher leverage. So we're in a really great position there. But we think that it is just prudent to have the discipline on the front end to say if oil is moving up, leaning in and when it's moving down lean out. So it prevents you from times like where like when we entered the year and oil was $57 and it seemed to be sort of $57 to $60 flat for ever to not go later in a bunch of hedges and then to bet that somehow like a conflict like we're living in sort of today would last forever as well. So we just have a disciplined hedge program that's instructed both by our balance sheet as well as just trying not to speculate on where oil price is trading.

Oliver Wong

And a question for Dave.

Darrin Henke

Oliver, we can't hear you here. And I think it sounds like everybody else is going to hear us fine. So it's probably best if we just try to catch up with you offline.

Operator

Your next question comes from John Abbott from Wolfe Research.

John Abbott

A couple of quick ones for us. I want to go back to the non-op here. So you talked about the -- I mean if you look at your overall production that you have currently, how much of that is non-op, approximately?

Darrin Henke

Yes, it's probably in the 10%, 15% neighborhood. .

John Abbott

All right. That's helpful. And then the second question is going to be on chemicals. You'll give us the update in February about what you may proceed with what treatments are you doing right now that seem to hold the most promise as you sort of look out there? And what are you waiting for in terms of data? You've been doing this for a little bit of time? How much data do you actually need to sort of make the decision to go forward?

Michael Lou

Yes. So we pumped a number of chemical treatments, and we talk about it on Page 7 in our deck. -- be it asset jobs and solvents, surfactants combination treatments. And we've -- on the production side, we've done hundreds of these type of jobs, and we're evaluating the productivity and evaluations, which one will give us the best ultimate returns on the dollars invested.

On the completion side, while we haven't pumped any chemicals as part of our completion jobs to date, we have been testing several chemicals in a lab situation and likely will result in pumping chemical jobs on completion in 2027. It's -- we're still evaluating that. But anyways, testing it in the lab. And of course, we're always studying what our competitors are doing, not only in the Bakken, but in the Permian, the Eagle Ford, et cetera. as well. So we'll definitely be early adopters as we continue to evaluate it on the completion side and having great results on the production side.

Operator

[Operator Instructions] Your next question comes from Geoff Jay from Daniel Energy Partners.

Geoff Jay

This is a really quick 1 for me. You mentioned that frac crews were tight. I'm wondering what you're seeing on the service inflation side kind of apart from fuel pass-throughs and consumables?

Michael Lou

Yes. On average, like we mentioned earlier, kind of in the low to mid-single digits is what we've seen so far this year. Some things are more, some things are less, but it's kind of where it's shaking out at this time. And not certain where 27 will be at this time, but I think it's really going to be a function of commodity price and activity levels. .

Operator

And there are no further questions at this time. I will turn the call over to Michael Lou, CEO, for closing remarks.

Michael Lou

Thanks, Julie. Once again, I'm honored to lead Chord and build on the strong foundation we've established and look forward to working with our employees, communities and other stakeholders to build on that progress. We have an incredibly talented team committed to executing our strategy and creating long-term value for our shareholders. Continuous improvement will remain a core objective. Additionally, Chord will maintain capital discipline while driving free cash flow per share and preserving a strong balance sheet. Thank you for your continued interest in Chord and for joining us this morning. We look forward to speaking to many of you in the coming weeks. Thank you.

Operator

Ladies and gentlemen, this concludes today's conference call. You may now disconnect.