Q3 2025 Comstock Resources Inc Earnings Call

Speaker #1: Good day and thank you for standing by . Welcome to the Q3 2025 COMSTOCK RESOURCES INC Earnings Conference Call . At this time , all participants are in listen only mode .

Speaker #1: After the speakers presentation , there will be a question and answer session . To ask a question during this session , you need to press star one one on your telephone .

Speaker #1: You would then hear an automated message advising your hand is raised . To withdraw your question , please press star one one again .

Speaker #1: Please be advised today's conference is being recorded . I would now like to turn the conference over to your first speaker today , Jay Allison , chairman and CEO .

Speaker #1: Please go ahead .

Speaker #2: All right . Again , I want to thank you for the introduction and thank those that are on the call . It's been a really good morning .

Speaker #2: You know , welcome to the COMSTOCK RESOURCES INC third quarter 2025 Financial and operating results conference call . You can view a slide presentation during or after this call by going to our website at WW COMSTOCK RESOURCES INC .

Speaker #2: Com and downloading the quarterly results presentation . There you'll find a presentation entitled Third Quarter 2025 results . And Jay Allison , Chief Executive Officer of Comstock .

Speaker #2: And with me is Roland Burns . Our president and CFO , Dan Harrison , our CEO and Ronald Mills , our VP of Finance and Investor Relations .

Speaker #2: Please refer to slide two in our presentations . And note that our discussions today will include forward looking statements within the meaning of securities laws .

Speaker #2: While we believe the expectations of such statements to be reasonable , there could be no assurance that such expectations will prove to be correct .

Speaker #2: If you'll flip over to slide three , you know , as we start the day , we are we are really excited to update our stakeholders on the company's progress so far this year .

Speaker #2: Comstock and our bold moves to create a Western extension of the Haynesville Shale have been the subject of several news stories recently , as the interest in natural gas has never been greater .

Speaker #2: I don't believe we have ever seen a brighter future for natural gas. Natural gas has become the go-to energy source in the United States, driven by the growth in LNG exports and the push to generate power for AI and data center development.

Speaker #2: I noticed yesterday that LNG exports reached a record high of 18.7 BCF , and the journal is full of articles on the impact of AI and data centers on future power demand .

Speaker #2: The Haynesville Shale is on the on the front line to deliver the gas supply to meet the growing demand . As one of the early pioneers in the Haynesville , we have focused our efforts over the last five years on being a leader in expanding the resource and the basin to be able to meet the new demand .

Speaker #2: The western Haynesville story is more about utilizing advancements in technology than geologic prospecting . As the existence of Haynesville and Bossier Shell in the area has been well known .

Speaker #2: Today , we're giving you a preview of the future by providing our estimates of the vast inventory of drilling locations in our emerging play in the western Haynesville .

Speaker #2: We also announced the divestiture of some of our legacy Haynesville assets , which we will not need in the future as we shift more of our resources to the Western Haynesville .

Speaker #2: The sale allows us to improve our balance sheet, as all of the proceeds were used to retire long-term debt. You know, this was also a very efficient quarter.

Speaker #2: And our legacy Haynesville drilling program , fueled by the additional drilling rig , we added at the beginning of the quarter , our drilling and completion costs in our Haynesville area averaged $1,229 for lateral foot .

Speaker #2: legacy Adjusted EBITDA for the quarter was $249 million , and we reported adjusted net income of $28 million , or $0.09 per diluted share .

Speaker #2: That is an industry leading number in the basin . The activity we added last quarter will drive production growth next year into a growing demand market .

Speaker #2: On slide three , we summarize the highlights of the third quarter . Our natural gas prices in the third quarter drove the improved financial results in the quarter compared to the third quarter of 2020 .

Speaker #2: For our natural gas and oil sales grew to $335 million . We generated $190 million of operating cash flow for $0.65 per diluted share .

Speaker #2: During the third quarter , we put three new Western Haynesville wells online , increasing the number of wells turned to sales in 2025 .

Speaker #2: In the western Haynesville to eight wells . Those three wells had an average lateral length of 8566ft , and an average per well initial production rate of 32,000,000 cubic feet per day , and our legacy Haynesville .

Speaker #2: We've now turned 28 wells to sales to date in 2025 , with an average lateral length of 11,919ft and a per well initial production rate of 25,000,000 cubic feet per day in September , we divested of our non-strategic on valley wells in East Texas and North Louisiana for net proceeds of $15.2 million .

Speaker #2: We also recently entered into an agreement to divest of our Shelby Trough assets in East Texas for $430 million in cash , and that is expected to close in December .

Speaker #2: On the next slide , I will cover the divestitures in more detail . Slide four . Visually , you can see this . It summarizes our recent divestitures in September , we sold our legacy Cotton Valley wells in East Texas , North Louisiana for net proceeds of $15.2 million .

Speaker #2: Our Cotton Valley properties , which we sold , included 880 or 770.9 net wells producing seven point 9,000,000 cubic feet per day , net to our interest in another 46 or 27.3 net in wells on October the 10th , we entered into an agreement to sell our Shelby trough properties in Nacogdoches and Augustine and Sabine counties for $430 million .

Speaker #2: These assets include 36,000 net acres with 155 or 74.5 , net wells producing nine point 3,000,000 cubic feet per day , net to our interest , the Shelby Trough sale is expected to close in December .

Speaker #2: I'll now turn it over to Roland to discuss the financial results reported today . Roland .

Speaker #3: All right . Thanks , Jay . Slide five . We cover our third quarter financial results . Production of the third quarter averaged 1.22 BCF a day , and our oil and gas sales in the quarter increased 10% from the third quarter of last year to $335 million .

Speaker #3: Ebitdax in the quarter was 249 million , and we generated 190 million of cash flow during the quarter . We reported adjusted net income of $28 million for the third quarter , or $0.09 per diluted share , compared to a loss in the same period in 2020 .

Speaker #3: For slide six , is the year to date results . Our production for the first nine months have averaged 1.24 BCF per day , and with improved natural gas prices , our oil and gas sales in the first nine months have increased 18% to $1.1 billion .

Speaker #3: EBITDA for the first nine months of 2025 was $802 million , and we generated $639 million of cash flow . We reported net income of $122 million for the first nine months of 2025 , or $0.41 per diluted share , as compared to a net loss for the same period last year .

Speaker #3: A slide seven we break down our natural gas price realizations . The quarterly IMX settlement gas gas price averaged $3.07 in the third quarter , and the average Henry Hub spot price averaged $3.03 , which is slightly below the settlement price .

Speaker #3: 28% of our gas was sold in the spot market , and the balance was sold in the index market . So the appropriate reference price for our gas was $3.06 .

Speaker #3: Our realized gas price during the third quarter averaged $2.75 , reflecting a $0.32 basis differential compared to the settlement price and a 30 $0.01 differential compared to the reference price in the third quarter , we were 57% hedged , which increased our realized gas price to $2.99 .

Speaker #3: We broke even from our third party gas marketing in the third quarter . On slide eight , we detail our operating costs for MCF and our EBITDA margin .

Speaker #3: Our operating costs per MCF averaged $0.77 in the third quarter , $0.03 lower than last quarter . Our EBITDA margin was 74% in the third quarter , which is unchanged from last quarter , lifting costs improved by $0.02 in the quarter .

Speaker #3: Production and ad valorem taxes were up by $0.01 and gathering in cash . G&A costs improved by $0.01 in the third quarter . On slide nine , we recap our spending on drilling and other development activity .

Speaker #3: We spent a total of $267 million on development activities in the third quarter , and $785 million for the first nine months of this year .

Speaker #3: In the first nine months of this year , we've drilled 25 or 21.8 net horizontal Haynesville wells and 11 or 10 net Bossier wells , for a total of 36 wells .

Speaker #3: We also turned 36 wells, or 30.9 net operated wells, to sales, which had an average initial production rate of 27,000,000 cubic feet per day.

Speaker #3: Slide ten recaps our capitalization at the end of the third quarter . We ended the quarter with $580 million of borrowings outstanding . Under our credit facility .

Speaker #3: Our borrowing base is at $2 billion under the credit facility and the elected commitment is 1.5 billion . Our last 12 months leverage ratio has improved to three times and will continue to improve as you get away from the 2024 results , which are weighed down by low natural gas prices .

Speaker #3: At the end of the third quarter , we had $239 million of liquidity . The sale of our Shelby Trough assets that is expected to close in December will improve the leverage ratio and enhance our and enhance our liquidity .

Speaker #3: Since the cash flow associated with the properties being sold was minimal, I'll now turn it over to Dan to discuss the drilling results.

Speaker #4: Okay , thanks , Roland . If you look on slide 11 , this is an overview of our latest acreage footprint in the Haynesville Bossier , shell and East Texas and North Louisiana .

Speaker #4: We now have 1,055,386 gross acres and 797,440 net acres that are prospective for the commercial development of the Haynesville and Bossier shales.

Speaker #4: This is our western Haynesville acreage footprint , which we've now grown to over 530,000 net acres . On the right is our 266,711 net acres in our legacy Haynesville area , we have 27 gross , 26.9 net wells currently producing on our western Haynesville acreage , which is virtually undeveloped compared to our legacy Haynesville area .

Speaker #4: Given the higher pay thickness and the higher pressures we encounter in the western Haynesville , we expect the western Haynesville will yield significantly more resource potential per section than our legacy Haynesville .

Speaker #4: On slide 12 , this outlines our new development plan utilizing the horseshoe lateral concept . The horseshoe well design concept combines the two separate and adjacent shorter laterals until a longer single lateral , which results in a much more efficient use of capital .

Speaker #4: We realize approximately 35% savings in our drilling costs . When we drill a ten K lateral horseshoe well , compared to a 5000 foot sectional lateral well .

Speaker #4: Our drilling inventory and our legacy Haynesville area now includes 118 horseshoe locations . During the third quarter , we completed our second horseshoe well to date , the Roberts 2623 number one had 11,453 foot lateral and a 26,000,000 cubic feet per day IP rate .

Speaker #4: To date this year , we have drilled one additional horseshoe well and we have another four horseshoe wells that are currently in progress .

Speaker #4: We plan to drill a total of eight horseshoe wells this year , and we plan to drill ten horseshoe Wells in 2026 . Slide 13 is our updated drilling inventory and our legacy Haynesville area .

Speaker #4: At the end of the third quarter . This is adjusted to exclude the locations we're selling in the Shelby Trough this quarter . We are now presenting our legacy Haynesville and our Western Haynesville drilling locations separately .

Speaker #4: Our total operated inventory in the legacy Haynesville consists of 1,039 gross locations and 809 net locations, which equates to a working interest of approximately 78%.

Speaker #4: Our Non-operated inventory in the legacy Haynesville includes 873 gross locations , 108 Net locations , and this represents a 12% average working interest .

Speaker #4: Our drilling inventory is comprised of short laterals , less than 5000 medium laterals , 25,000 to 8500ft . Are long laterals , between 8500 and 10,000ft , and our extra long laterals for all the wells over 10,000ft in our gross operated inventory in the legacy Haynesville , we have 36 short laterals , 157 medium laterals , 425 long laterals , and 421 extra long laterals .

Speaker #4: Our gross operating inventory is split 51% in the Haynesville and 49% in the Bossier. Over 80% of our gross operated inventory in the legacy Haynesville consists of laterals that are greater than 8,500 feet.

Speaker #4: The 118 horseshoe locations mentioned on the previous mentioned on the previous slide are all in our legacy area . The average lateral length in inventory is now up to 9961ft .

Speaker #4: This is up 275ft from the end of the second quarter . So our inventory provides us with decades of future drilling locations based on based on our current activity levels .

Speaker #4: On slide 14, we show our estimated drilling inventory in the western Haynesville. This represents the first time we've disclosed our western Haynesville inventory, and our total inventory in the western Haynesville consists of 3,332 gross locations.

Speaker #4: In 2559 net locations . This equates to a working interest of about 77% . As much of our as much of our western Haynesville acreage is not unitized , and that locations here are estimated in the western Haynesville .

Speaker #4: The inventory is more weighted to the Bossier Formation , with 3,036% of the inventory in Haynesville and 64% of inventory in the Bossier .

Speaker #4: The same as our legacy Haynesville inventory . Our western Haynesville inventory is broken down into groups of short laterals less than the 5000ft are medium laterals between 5000 and 8500ft .

Speaker #4: Our long laterals between 8500 and 10,000ft , and our extra long laterals over 10,000ft . In our western Haynesville and the gross operated inventory , we assume we have no short laterals .

Speaker #4: We have 1347 medium laterals , 642 long laterals , and 1343 extra long laterals . So approximately 60% of this gross operated inventory in the western Haynesville consists of laterals greater than 8500ft .

Speaker #4: On slide 15 is a chart outlining our average lateral length that we've drilled . This is based on wells that have reached total depth .

Speaker #4: The average lateral lengths are shown separately for both our legacy Haynesville and Western Haynesville areas. In the third quarter, we drilled 11 wells to total depth in the legacy Haynesville, and these had an average lateral length of 12,593 ft.

Speaker #4: The individual lengths ranged from 4968ft , up to 15,466ft . Our record long lateral and our legacy Haynesville area still stands at 17,409ft .

Speaker #4: In the third quarter , we drilled six wells to total depth in the western Haynesville . These wells had an average lateral length of 10,158ft .

Speaker #4: The individual lengths here ranged from 7809ft up to 12,710ft . Our longest lateral drill to date in the western Haynesville . Still stands at 12,763ft .

Speaker #4: To date , the western Haynesville we have drilled 15 wells with laterals longer than 10,000ft , and we have drilled six wells with laterals over 12,000ft .

Speaker #4: Slide 16 outlines the wells that were turned to cells on our legacy Haynesville acreage . This year . So far this year , we've turned 28 wells to cells in our legacy Haynesville area .

Speaker #4: The individual IP rates on these wells range from 16 million today , up to 37,000,000 cubic feet a day . And the average was 25,000,000 cubic feet a day .

Speaker #4: The average lateral length was 11,919ft , with the individual wells ranging from 9252ft up to 17,409ft , just to recap , four of our eight rigs are drilling on our legacy Haynesville acreage .

Speaker #4: Slide 17 outlines the eight wells that we have turned to sales in the western Haynesville this year since we last reported our earnings , we have turned three additional wells to sales .

Speaker #4: These three wells had an average lateral length of 8,566 ft and an average initial production rate of 32,000,000 cubic feet per day. Additionally, four of our rigs are drilling on our western Haynesville acreage.

Speaker #4: Slide 18 highlights the average drilling days and the average footage drilled per day in the legacy Haynesville area . For our benchmark long lateral wells , these are wells that are greater than 8500ft long .

Speaker #4: In the third quarter , we drilled ten benchmark long lateral wells to total depth in the legacy Haynesville . And these wells averaged 26 days to total depth .

Speaker #4: We have averaged we've averaged 26 days consistently for the last three quarters . In the third quarter , we averaged 1004ft drilled per day on our legacy Haynesville acreage .

Speaker #4: This is a 4.5% increase versus the second quarter of 2025 , and a 2% increase versus the 2024 full year average of 987ft drilled per day .

Speaker #4: The best wells drilled to date in the legacy Haynesville still stands at 1461ft , which was drilled to TD in 14 days . Slide 19 .

Speaker #4: This highlights our drilling progress in the western Haynesville . During the third quarter . We we drilled six wells to total depth in the western Haynesville .

Speaker #4: We now have a total of 35 wells that we have drilled to total depth through the end of the quarter . We averaged 52 drilling days for the six wells , drilled to total depth in the third quarter .

Speaker #4: This represents a decrease of three days compared to the second quarter and a decrease of seven days compared to our 2024 full year average of 59 days .

Speaker #4: Our fastest well drilled to date still stands at the 37 day mark , and that was drilled with a 12,045 foot lateral . Over on slide 20 is a summary of our DNC cost through the third quarter for our benchmark loan .

Speaker #4: Lateral wells located on our legacy Haynesville acreage . These costs reflect all our legacy wells drilled with laterals greater than 8500ft long . The drilling costs are based on when the wells reached TD and the completion costs are based on when the wells are turned to cells .

Speaker #4: During the third quarter, we drilled ten of our benchmark loan lateral wells to total depth. The third quarter drilling cost averaged $558 per foot.

Speaker #4: This is a 15% decrease compared to the second quarter . We had an abnormally high drilling cost in the second quarter due to drilling difficulties that were associated with some highly overpressured zones , and during the third quarter , we turned a nine wells to cells on our legacy Haynesville acreage .

Speaker #4: The third quarter completion cost came in at $671 a foot . This represents a 7% decrease compared to the second quarter . These lower completion costs are due to a combination of .

Speaker #4: We had lower frac pricing, lower fuel costs, with all of our wells using natural gas, blended fuel, and also the longer laterals.

Speaker #4: In the third quarter , just we got four rigs running that are running on our legacy Haynesville acreage . Slide 21 is a summary of the DNC costs through the end of the third quarter .

Speaker #4: For the wells drilled in the western Haynesville . During the quarter , we drilled six wells to total depth with an average lateral length of 10,158ft .

Speaker #4: The third quarter drilling cost averaged $1,385 a foot . This represents a 24% decrease compared to the second quarter , but is more in line with our previous quarter's .

Speaker #4: The primary factor for the lower drilling cost in the third quarter is the longer laterals . Our average lateral length in the second quarter was very low at 7933ft , compared to an average lateral length of 10,158ft in the third quarter .

Speaker #4: During the quarter , we also turned three wells to sales on our western Haynesville acreage . These had an average lateral length of 8566ft .

Speaker #4: We didn't turn for this year . We didn't turn any wells to sales in the first quarter . The third quarter completion cost averaged $1,622 a foot .

Speaker #4: This is a 24% increase compared to the second quarter , and the higher completion cost was primarily due to the higher frac cost .

Speaker #4: We had on had on the wells and a lesser extent to a lesser extent . The shorter average lateral length . We did have some higher than normal horsepower usage associated with fracking .

Speaker #4: These wells , which were considerably deeper than our average Western Haynesville well , and we observe some higher frac gradients at these deeper depths .

Speaker #4: To kind of recap , our activity levels , we've got four rigs running in the western Haynesville , and we got four rigs running in the on our legacy Haynesville acreage .

Speaker #4: We also have two full time dedicated frac fleets that we are running between , both our legacy Haynesville area and our western Haynesville areas .

Speaker #4: And I'll now turn the call back over to Jack .

Speaker #2: All right . Great job , Dan and Roland , please refer to slide 22 where we summarize our outlook for 2025 . In 2025 , we remain primarily focused on building our great assets in Western Haynesville .

Speaker #2: That will position us to benefit from the longer term growth in natural gas demand . And we currently have four operating rigs drilling in western Haynesville to continue to delineate the new play .

Speaker #2: We expect to drill 19 wells in Turn 13 and to sell in western Haynesville this year. We'll continue to build out our western Haynesville midstream assets to keep up with the growing production from the area.

Speaker #2: Our new market gas treating plant started operations in July , which more than doubled our gas treating capacity in the legacy Haynesville . We're currently running four rigs to build production back up in 2026 .

Speaker #2: We expect to drill 33 or 25.6 net wells and turn 35 or 28.2 net wells to sales , into legacy Haynesville this year , we continue to have the industry's lowest producing cost structure and expect drilling efficiencies to continue to work toward driving down drilling and completion costs in 2025 .

Speaker #2: In both the Western and legacy Haynesville areas , as stated earlier , we have strong financial liquidity totaling more than $900 million , which will be enhanced with proceeds from the Shelby Trough divestiture , which is expected to close in December 2025 .

Speaker #2: If you have any specific questions on guidance for the rest of the year , please feel free to reach out to Ronald Mills .

Speaker #2: Ron .

Speaker #4: Antoine . We .

Speaker #5: Can turn it over to Q&A .

Speaker #1: Thank you . At this time , we will conduct a question and answer session as a reminder to ask a question , you will need to press star one one on your telephone and wait for your name to be announced .

Speaker #1: To withdraw your . To withdraw your question , please press star one one again . Please stand by while I compile the Q&A roster .

Speaker #1: Our first question comes from Derek Whitfield from Texas Capital . Please go ahead .

Speaker #6: Good morning and thanks for your time .

Speaker #2: Good morning .

Speaker #6: I wanted to start with a broader question around 2026 and not to pin you guys down on any numbers , but really just want to think about it from the standpoint of the higher level of activity you're carrying into 2026 and the operational efficiencies you've gained in both the western Haynesville and legacy Haynesville .

Speaker #6: Could you speak to the broader capital efficiency gains you'd expect as you enter the year ?

Speaker #4: Yeah , I'd say , you know , we've if you kind of they're kind of two different animals . The legacy Haynesville versus the western Haynesville .

Speaker #4: I mean the efficiency gains in the , you know , the legacy area . We've pretty much you know , we're kind of up at the top of the curve there .

Speaker #4: I think we've picked up a lot . Obviously , since we've added the Horseshoe Wells , you know , as far as just being able to convert a lot of our shorter wells to longer wells , I think we've seen more efficiency there .

Speaker #4: The Horseshoe wells are going great for us , really . The efficiency gains that we're still looking to pick up and have been , you know , still up on the learning curve is in the western Haynesville .

Speaker #4: We've got a lot of , you know , we've had a lot of improvements we've made to date . We've still got some a few other things kind of , you know , coming down the pike that we're going to be we're going to be looking at implementing in the western Haynesville to help , help our efficiencies .

Speaker #4: There . But , you know , I think I think the four rigs that we got running in Western Haynesville is a good activity level for us .

Speaker #4: You know , we're able to learn a lot from it . We've got we've got we've made a lot of improvements in our downhole performance and , you know , like I said , we just got a few things in the mill that are kind of kind of turning that are going to help us out .

Speaker #4: We think in this next year, in 2026.

Speaker #2: You know , Derrick , you commented that we've had solid Western Haynesville . Well results . And I just like to comment on Dan , the very first Haynesville .

Speaker #2: Well , we ever drilled back in oh eight , Dan was involved with it . So for 17 years he's touched every Bossier or Haynesville well .

Speaker #2: We drilled either be in the core or in western Haynesville . So , you know , he has complete authority to to to de-risk and , and optimize the cost on the new Western Haynesville play .

Speaker #2: It's important .

Speaker #5: And just capital efficiency standpoint . You know , we did we are carrying some capital this year for the for the addition of that eighth rig with no production really showing up until sometime in the first or second quarter of next year .

Speaker #5: So when you think about your typical capital efficiency , that should that should drive improved capital efficiency next year .

Speaker #6: Great for my follow up . I wanted to shift over to gas marking more specifically , I love your perspective on how you see gas and gas competition and folding along the Gulf Coast .

Speaker #6: As you think about your supply advantage of being able to deliver gas into Sabine Pass and the competing demand opportunities between LNG and PowerGen .

Speaker #6: You're arguably in a great position to benefit from both in terms of gas realizations .

Speaker #3: Yeah , that's that's a good observation . Derek . Yeah , I think that especially owning our own midstream and the western Haynesville is going to be really a huge asset for us in the future as as we're able to kind of instead of having to go through other midstream companies and long haul pipelines , you know , we can create great markets , you know , right there that we can directly sell to end users and become a very reliable supplier .

Speaker #3: And I think that's what a lot of these, you know, large users with new demand are looking to establish: direct relationships with the producers.

Speaker #3: And you've heard a lot of that about that in our industry . So I think we're well positioned there . Given that we control the infrastructure , the midstream and obviously a great location .

Speaker #3: We're , you know , you know , yeah , the gas can can support all the growth in Texas . And then , you know , with the the Port Arthur LNG , you know , very , very close to being connected to that .

Speaker #3: So yeah , I think that's a big part of the future of for natural gas is not only having the natural gas , but being able to get it directly to the , to the end user .

Speaker #2: Well , Derek , I think is , you know , if you look at location , location , location , I mean , 100 miles from Dallas and the same distance from Houston and really close to LNG corridor , you're perfectly situated for both AI data centers and LNG .

Speaker #2: So you couldn't be in a better area . And then the fact that , you know , this is not an exploration play , it's really a development play for the geology that was there .

Speaker #2: So it's been a very , very , very active . Oil and gas region for 30 plus years . So for us to just deepen these wells with the new technology in a great footprint where we're located , you know , and maybe 6000 of these acres are dedicated to restaurant dedicated .

Speaker #2: That's why we say , you know , we we , we we're around a big , you know , bright light bulb . And then people are calling because of the inventory , which inventory is the holy grail ?

Speaker #2: I mean , that's why you see people expanding to look at this , play . It is the holy grail . You got to have inventory .

Speaker #6: Thanks for your comments . I'll turn it back to the operator .

Speaker #1: Thank you . One moment for . Our next question comes from Charles Mead from Johnson Rice . Please go ahead .

Speaker #7: Good morning , Jay , to you and your whole team there .

Speaker #2: Hello , Charles .

Speaker #7: Thank you for the warm welcome . Jay , I want to I want to ask you about the the Shelby trough sale that looks to it looks to us like that's a really a great outcome for you guys as far as what what the seller paid for those undeveloped locations .

Speaker #7: So I wanted to I wanted to see how you would characterize it , how how happy you were with those proceeds . And then and ask if there's anything left in your portfolio that would , you know , that could fit that same appetite for for people who are willing to , you know , pay for those undeveloped locations ?

Speaker #2: Well , first of all , Charles , I think it's a total win win for everybody . I mean , we we're we're really unicorn out there because we have so much inventory .

Speaker #2: You know , as we just announced , we almost had 2600 locations net in the Western Angel that that's that's a big gift that we've been working on for five years .

Speaker #2: So if you look at other really good locations that that might be for sale . I mean , I think is a really smart buy by the buyer .

Speaker #2: I think we , you know , we we needed to pay down the debt on our balance sheet because we'd incurred a lot of money as our investment in the western Haynesville .

Speaker #2: And we look at that , you know , we trimmed some of the vertical wells , those 900 or so vertical wells , as we sold those early on .

Speaker #2: So so we are always looking as we de-risk and kind of fortify our acreage position . Western Angel , is there anything else we can do ?

Speaker #2: And that is to adjust the balance sheet because we need to get our leverage lower . So I was pleased with how both of those transactions came about .

Speaker #2: And again , we always look to see Charles , as you well know . What can we do as a company position where we think we are to become a stronger company in the light of , you know , AI data center demand and LNG demand .

Speaker #2: That's the only thing we do . And , you know , I think , I think everybody won in the trade great locations .

Speaker #2: And we didn't need to be drilling them because we're drilling the Western Haynesville .

Speaker #7: Got it . And then the follow up , following on that same thread , I want to say thank you for sharing this Western , Western Haynesville location .

Speaker #7: Count . And I just want to ask a couple of questions around , you know , your assumptions and the dynamics there . Just using the kind back of the envelope math .

Speaker #7: It looks like you guys have been pretty conservative in your in your assumptions on on number of zones and spacing across zones . But I wonder if you could you could share what what the if you'd be willing to share what the assumptions are in that , you know , I think that 2500 2600 number and also I think Dan alluded to this in his in his prepared remarks that perhaps the perhaps because not a lot of the acreage is unitized yet that that's actually preventing you from , from counting location and , and you know , my assumption is that would get worked out over time .

Speaker #7: But maybe you can you can fold that into the assumptions on the location count .

Speaker #3: I'm sure . I think we tried to be conservative on how we looked at , you know . Well , spacing and benches and the play , you know , because you obviously don't want to start out at a high number and bring it down .

Speaker #3: But we think they're very you know , it's a very realistic view of the inventory . The comment that was made about the working interest in our legacy , Haynesville inventory , I mean , every single location there is pretty exact we know the exact we know what unit it's in .

Speaker #3: We know our working interest with precision . And the western Haynesville , those units are being put together still . So , you know , the exact working interest in the units is not 100% known .

Speaker #3: You know , so far , most of the wells , you know , we've had 100% working interest in . So we we , you know , just looked at our acreage ownership and just made some rougher assumptions there .

Speaker #3: So it's just doesn't have the level of precision . But I don't think it's a significant , you know , you know , you know , I think we're within the margin of error as far as looking at , you know , how we present the net numbers .

Speaker #2: Yeah . And Charles , you always discount it back . You know , you say here's what you could have here's kind of a high low number .

Speaker #2: And then you discount it back and say , okay , what is a number that we can throw out right now that we think , you know , with some bookends on , we have a chance of achieving .

Speaker #2: And like Paul said , you don't want to be aggressive . And then all of a sudden you have a few less . And you , you know , you're a loser .

Speaker #2: So we want to throw that out and just say again with with an asterisk that , you know , we've not unitized some of those locations .

Speaker #2: So it's a guesstimate .

Speaker #7: Got it . That's great detail . Thank you .

Speaker #2: Yeah . Great questions .

Speaker #1: Thank you . Our next question comes from Callie Akamine from Bank of America . Please go ahead .

Speaker #8: Hey, good morning, guys. Jay Rowland. I want to start on the Western Haynesville disclosure, and maybe first off, I think putting your expectations in print really shows your conviction in the asset. For my question, I want to follow up on the unitization comment.

Speaker #8: You've got some short laterals in that table . 5000 to 8500ft . But this is a large , contiguous position . So my question is , what's stopping you from doing the land work to optimize the entire position ?

Speaker #8: Around 10,000 foot laterals . And if that's possible , how long would that work ? Take ?

Speaker #3: Yeah , that's a that's a great question to look . But I think there are there are some areas that where there's some there's an ownership where there's , you know , some other operators to , you know , that we've already kind of identified that we're , you know , we're keeping out of our units .

Speaker #3: So we've chosen those those shorter laterals , just like the , you know , the wells we completed , you know , this quarter and drilled last quarter , that a lot of that was defined by kind of the acreage ownership .

Speaker #3: And so we've honored that , you know , we're we don't have it completely contiguous . So I think and then there's there's some there's obviously geologic structures that we have identified on seismic that we , you know , are avoiding and not wanting to develop .

Speaker #3: You know , and around and so , you know , we've tried we've honored a lot of our geologic work to in those assumptions .

Speaker #3: But it's still , you know , early on you'll be able to probably optimize that over time . And then a lot will depend on how long do you really want to go ?

Speaker #3: Do you want to go to 15,000 foot laterals ? And some of that is I think there's room to optimize in the future .

Speaker #3: But I think this was a really good view of how we see the acreage we currently own . Now . We could also lease additional acreage that will change the configuration in the future , and I'm sure that will happen .

Speaker #3: We're always picking up additional acreage as we as we put units together . So there will be a there will be moving parts .

Speaker #3: But I do feel like this was a pretty thorough look at if we stopped leasing . You know what it could look like now .

Speaker #2: Well , and Kelly , you know , we added , you know , 5000 acres from the last time we reported . So we do clean up stuff all the time in the Western Angel , just like we do in the court .

Speaker #2: This is a pretty , you know , safe conservative number . We we've we think that we have least 90% of what we think the real value is in the western Haynesville .

Speaker #2: And maybe that's expanded and that'll be a good thing . We hope it does expand , but based upon the control that we have and the size that we have and the , well results we have , you know , I think that we're pretty good shape there , but we do keep we keep trying to make it better .

Speaker #2: And at some point in time , we won't own 100% of all the wells . But until that time is right , you know , we'll we'll kind of drill the lateral lengths that we need to to keep the information that we need to keep kind of in our back pocket right now .

Speaker #8: Thank you for that, guys. For my second question, I want to ask about the second train at the Marquis gas plant.

Speaker #8: That build looks like it's going to take you to about 1.3 years from 900,000,000 cubic feet . So that's quite the scale . My question is , was this part of the original scope of the JV deal with quantum ?

Speaker #8: And then can you talk about the capacity utilization at those plants ? What is it today ? And once Marquis two is online , perhaps in 27 , where do you think the utilization rate will be at that time ?

Speaker #3: I don't know if we want to forecast a utilization rate that's getting way out there . But , you know , we are you know , when we originally put together the plan for pinnacle , the pinnacle gas services and how to service the development program , I mean , that obviously we saw and we've commented this a long time ago , that we saw trying to create a treating infrastructure to handle up to two B's of gross production .

Speaker #3: You know , over the next five , six , seven years . So I think this is a the second phase of Marquis is just is was the next step .

Speaker #3: That was in our original plan . And then there's a , you know , another , you know , either debating on either a expansion at Bethel or a third gas plant will probably be something way off .

Speaker #3: Next in the future . But we we do have to keep ahead . You know , we obviously have to to provide for the treating way ahead of when we're going to actually produce it .

Speaker #3: It's not going to be a just in time kind of delivery , obviously , because it takes a good 12 to 18 months to to to put those together .

Speaker #3: So yeah , right now on market to market phase two , we're we've got a lot of long lead time , a components and equipment that are being manufactured that , you know , we have to go out and order and and so that's kind of the big process going on now .

Speaker #3: You know for for something that we can hopefully open up next summer would be our , our goal for that .

Speaker #2: And yeah , I think the key answer to that is we have a lot of inventory . But we own our midstream as Rolla mentioned during the beginning , comments .

Speaker #2: And , you know , we have an incredible financial partner with quantum . And we look to see what our drilling inventory looks like .

Speaker #2: We see what our performance looks like. We see what our acreage addition looks like. And then, based upon all that, we control the gathering.

Speaker #2: And as far as the takeaway and the demand , as we said , you know , 45 minutes ago , it has never , ever looked brighter out there for what what the world needs , not just America .

Speaker #2: The world needs in in the form of natural gas . I think we're right there at the right time .

Speaker #3: But , you know , there are other operators or a couple other operators with which are running rigs in the area . You know , and so , you know , a lot of that will how we actually build out also depend on do we end up picking up some of that gas or not .

Speaker #3: And so that's all . You know , a lot of that is the kind of remain to be seen in the future . But there will be other there's other activity in the area that hopefully that we kind of see coming to pinnacle over time , too , as we build out , you know , that great asset that underlies the Haynesville .

Speaker #3: .

Speaker #8: Guys , I appreciate all that color . Thank you .

Speaker #1: Thank you . Our next question comes from Carlos as Caliente from Wolfe Research . Please go ahead .

Speaker #9: Thank you . I love the the way the operator said my name . It's caliente . Good morning , Jay Rowland . And Dan .

Speaker #9: I want to go back to to one of your comments . Jay , you said , you know , hopefully the Western Haynesville , the footprint that you guys have at least expands and nice wordplay .

Speaker #9: By the way . But look , you've done a great job at establishing the core with just under 30 kills across the play , especially in that southern corridor across Leon and Robertson with what I think that in what is incremental data proving up acreage to the north of that as well , however , you've seen recent leasing in M&A activity flowed into the east and southeast , particularly in Anderson and Houston .

Speaker #9: So I wonder when you see that , do you think the core do you think there's likelihood that the core of the basin could actually be much larger and it extends into potentially some of your other wells that you've killed earlier this year ?

Speaker #9: So in part, it beats the question, if I may. Along the same lines, if you look at it, it looks like you have a permit.

Speaker #9: Well, neurologic, one, if maybe you can touch on when you plan to go back to this area as well. Thank you.

Speaker #2: Well , yeah , I the comment should be because of Jerry Jones and because of his , you know , big and plus dollar investment in the company .

Speaker #2: We could we could literally think and not only think Carlos , we could act out of the box . And because of the fact that we we've always been leaning toward natural gas , I mean , and we're one of the , the frontrunners and the core of the of the legacy Haynesville area .

Speaker #2: But Jerry Jones said , you know , here's a well , we showed it . We could drill it and it's a circle and well , that that over the last five years has proved to to be as successful .

Speaker #2: So as we move to the call we have today , over five years , in looking at the seismic 2D , 3D , looking at the wellbore penetrations , looking at the performance of the 3040 wells , we've either drilled , completed or drilling what we look at , we say we're very comfortable that , you know , this is probably 90% of the real value .

Speaker #2: Now , you know , as as as you look at Aton . Aton says there are monster wells out there . I love that they say that .

Speaker #2: And we've hit a bunch of them . But , you know , that's a credible company . Mitsui , to come in their smart management .

Speaker #2: Smart . Their money , smart . You know , they come in , you know , expand is they're doing what their name says , expanding their name says expanding .

Speaker #2: And they're expanding into the western Haynesville . Because why , as I said earlier , the locations are the Holy Grail . I mean , you can do M&A , M&A , M&A , but that doesn't add any new locations on planet Earth .

Speaker #2: It gives you more under your umbrella . But we've tried to , you know , to address the problem and the problem is can you really add new inventory .

Speaker #2: And that's where , you know , the prior question was asked , what's your inventory count ? And I think we're pretty accurate on , you know , 25 2600 net locations .

Speaker #2: That's an incredible number . You know , 2600 locations is incredible number . So we are always looking for to see . Do you go east .

Speaker #2: Do you go south? Do you go? Everybody is always doing that. And you know what? There's going to be some gems out there.

Speaker #2: And I hope that . I hope they are found because all that does is make our acreage more valuable in , in our opinion .

Speaker #4: And I'll , I'll add you , add you asked about permitted well up by the Olajuwon . We do we actually did Spud .

Speaker #4: We got a two well pad that's up there near the lodge . And that that pad was spud last week .

Speaker #3: So that will be one Bossier, one Haynesville.

Speaker #4: Yeah. We got one. The Olajuwon is producing from Haynesville, and the new pad that we spud last week will be an additional Haynesville.

Speaker #4: Well and a Bossier test . Our first Bossier test up there .

Speaker #2: Yeah . And , you know , we're coring up in that area to . .

Speaker #4: That's correct .

Speaker #2: So that's that's at the cause we've had and we were you know , we're coring there also . .

Speaker #9: That's terrific color guys . Appreciate that . And real quick , if I can sneak in my follow up , you mentioned Asian J .

Speaker #9: And if I may I think one of your wells this order the well two wells the McCullough Wells are nearby that area . We've seen they're they're type curve to be quite outstanding in terms of production plateau and obviously this well is very strong in terms of initial production .

Speaker #9: So, I guess my question is: is there anything that you're looking at in terms of what they're doing, or any kind of near-term collaboration that you can potentially benefit from in terms of what you do? Or has it been more a separate effort from that standpoint?

Speaker #2: Well , you know , we've done some or in a process in some acreage swaps with them so they can drill longer laterals .

Speaker #2: We can drill some longer laterals in areas that we want to drill, and they want to drill, but I don't have any other comments on that.

Speaker #2: Dan, etc., versus Peyton, I mean.

Speaker #3: But it's always very when you have other operators doing things differently , it's always a great learning for a basin . So that's one thing that the Western Haynesville hasn't had near as much of as the original Haynesville had .

Speaker #3: But , you know , as we have some new other operators and there there were the first one out there . And so it's going to be , I think , very incremental to us learning how to properly produce the wells and drill the wells .

Speaker #3: The more activity , the more learning is going to be . The better for all the operators .

Speaker #2: Yeah . If you have four , or five more new operators come in . I think everybody , particularly Comstock , the learning curve is shortened .

Speaker #2: I think it'd be a great thing .

Speaker #4: Yeah , I think I think what you see is all the operators obviously they all kind of do something a little bit different , bigger frack , smaller fracs , you know how they draw their wells down , you know , what kind of casing design , you know , bigger hole laterals , slimmer hole laterals .

Speaker #4: So all of those things , I think when you get more of that in the pot and start looking at the results , you know , like we say , that's definitely going to help everybody .

Speaker #9: Thank you . Thank you for having me on .

Speaker #2: Thanks , Carlos .

Speaker #1: Thank you . To ask a question , please press star one one on your telephone and wait for your name to be announced .

Speaker #1: In the interest of time , we ask that you please ask one question and one follow up . Our next question comes from Kevin McCurdy from Pickering Energy Partners .

Speaker #1: Please go ahead .

Speaker #10: Hey . Good morning . Thanks for taking my question . No , you haven't put out a 2026 guide yet , but is there any color you can provide on how you plan to prosecute the Western Haynesville next year ?

Speaker #10: I'm looking for any thoughts on holding acreage versus development the size of the pads you might drill and lateral lengths as well as I think you kind of touched on where where you might be drilling , but any more color on that would be helpful too .

Speaker #3: I think . That , yeah , the 90% of the plan is going to be holding acreage , as we said , you know , we still have a lot of term acreage that we lease in the play .

Speaker #3: And so that's , that's that's a big part of where we want to drill the wells . So it's going to be following , you know , where we lease the time frame released and yeah .

Speaker #3: And so I think that that's that's , that's how we look at it I think . Yeah . The activity level of four rigs that we have operating , you know , is , is sufficient to kind of accomplish all that and not have to worry about losing any acreage that we don't drill , that we want to drill

Speaker #3: . And

Speaker #4: Yeah . And I

Speaker #4: think you're going to see in 2026 more of a Wells , will , you know , will continue to kind of push more in that , you know , northerly north eastern direction along the trend of where the acreage is .

Speaker #10: Great . I appreciate that detail . And then just a question on slide 13 and 14 on your your inventory , just to confirm , were the changes in the the legacy Haynesville and Bossier share , was that just driven by the by the asset sales or was there anything else that that changed in those inventory numbers ?

Speaker #3: Well , one , one time we had some of the western Haynesville in there , probably a small amount that was based on just the wells we drilled .

Speaker #3: , you know , the direct offsets , etc. , that you obviously have in the inventory . And so that's why we kind of chose to out , but it really wasn't really represented much in the original chart .

Speaker #3: So you had that . Plus you had you know , obviously we had the , the acreage that we sold or are in the process of selling that .

Speaker #3: We also removed those locations . And then there's always continued recalibration as you know , as wells are , and we find a way to make the laterals longer typically is kind of you could see that the feed continues to get larger .

Speaker #3: You know , average foot of that lateral . So that's that's always a process that would continue to optimize .

Speaker #10: Thank you for taking my question .

Speaker #1: Thank you. Our next question comes from Jacob Roberts from TF & Co. Please go ahead.

Speaker #11: Good morning .

Speaker #2: Morning .

Speaker #11: I wanted to circle back to a Q2 item . One of the things that was discussed was some experimentation on choke management in the western Haynesville .

Speaker #11: And I understand that we probably don't have enough data to make a final call , but I'm just wondering if you could talk about maybe the varying methodologies you've applied to the three that came online last quarter , and then the handful that are going to be coming online in the year ?

Speaker #4: Yeah , we got the three that we turned to sales in the last quarter . We've got four new and four new wells that are turning to sales here in the fourth quarter .

Speaker #4: We have had some we have varied it a little bit . I'd say we haven't done anything that's been extremely conservative to date .

Speaker #4: You know , we're taking some of the information from the cause and we're still , you know , doing a lot of detailed rate transient analysis .

Speaker #4: And , you know , basically , I think it's telling us , obviously , the more conservative drawdown is what we need to be following .

Speaker #4: And I think , you know , for the future , we're still looking to transition . You know , more into that , probably more conservative approach from where we started at .

Speaker #11: Great . Thank you Jay . Earlier you mentioned AI data centers . That type of stuff as well as as LNG demand , which have both been hugely topical .

Speaker #11: But recently, we saw one of your peers sign a sizable industrial contract at a premium to Nimax over in Louisiana. I'm curious if you could talk about that market, how you see it evolving, and maybe Comstock's willingness to participate in industrial agreements moving forward?

Speaker #3: Sure . That's a that's a great market , especially in the along the river corridor area and areas along the Gulf Coast , where there are new , you know , new industrial plastic plants , etc.

Speaker #3: , that are being built . Fertilizer plants and they're competing , obviously , with LNG feedstock gas , you know , so those those customers have been reaching out and interested in long term supply deals where , you know , years ago they would never interested in that .

Speaker #3: They would just go get gas . You know , in the in the monthly market , it was easy to get . So I think you do see I think over time we see a lot of our market and other other producers in the area wanting to establish , you know , having more direct sales to end users , capturing more of the value , the value chain .

Speaker #3: And , you know , better margins versus , you know , having the the midstream companies , you know , take off a lot of that margin .

Speaker #3: And so, you know, a lot of us are working on long-term plans like that as we are too.

Speaker #11: Great appreciate the time, guys.

Speaker #2: Thank you .

Speaker #1: Thank you. Our next question comes from Philips Johnston from Capital One. Please go ahead.

Speaker #2: Hello , Philip .

Speaker #5: Hey .

Speaker #12: Thanks for hey , thanks for the time and congrats on the asset sales . My my first question is really just a housekeeping question for Roland on the Shelby trough sale .

Speaker #12: Would you expect any tax leakage on the gross proceeds?

Speaker #3: Yeah , that's a that's a good question . No , we really have lots of tax attributes that actually that , you know , and we do expect a fairly sizable gain on that transaction because of , you know , we acquired that acreage way back with the Covey Park acquisition .

Speaker #3: And it wasn't a big part of that value that got allocated . Then . So , you know , there is a pretty sizable book and tax gain that we expect .

Speaker #3: You'll kind of see some some of that in the 10-q when we file it later today . But but we think we have a lot of tax attributes that will just be able to utilize .

Speaker #3: And so we don't see any cash , you know , real cash tax impact of that .

Speaker #12: Okay . Sounds good . Then a question for Dan . And it's really a follow up on Carlos . And Kevin's questions . It sounds like the two well pad neurological .

Speaker #12: One is kicked off, which is good to hear. Can you maybe just give us a guesstimate of how many wells are up in that northern step-out area?

Speaker #12: Might be considered for next year , or what percentage of the total might be up in that area ?

Speaker #4: Good question . We do have more wells planned for up in the area up there . I the number of , you know , escapes me off the top of my head , but we do really like that area up there .

Speaker #4: The Olajuwon is performing extremely well , super happy with it . So our next step , you know , is on this two well pad is to test the bossier , which is much thicker up there .

Speaker #4: So we want to get a good read on the bossier . And then , you know , we'll kind of kind of kind of go from there as far as how we're going to develop out that bench in that area .

Speaker #4: But we do have . I'm going to say , you know , 5 or 6 wells kind of planned up in that area for next year , kind of around , you know , just around that general area .

Speaker #12: Yep . Okay . Perfect . Thank you .

Speaker #1: Thank you . Our next question comes from Noel Parks from Toll Brothers Investment Research . Please go ahead .

Speaker #13: Hi . Good morning . Good . I just had a couple . Hey . How are you doing ? You know , you did touch a bit on it , but with the the New treatment capacity , you have the new plant coming online .

Speaker #13: Have you talked much about sort of like the , the economics of , of it sort of the in-house economics versus the third party opportunity , you know , while you're kind of in the , the ramp up mode .

Speaker #3: Yeah , I think that's been something we've been studying . Obviously , you know , because we don't , you know , a large part of , of a of your cost for treating is really the is all the facilities you build .

Speaker #3: And then once you build them , if you can utilize them , you're actually operating costs can be very , very , very , very low .

Speaker #3: Just the actual operating cost associated with it . But you have to recover the capital . So that's kind of where a lot of the costs are .

Speaker #3: So if you obviously if you own it yourself , you can what you recover it . You don't have to you don't have to keep recovering it .

Speaker #3: If you allow a third party to provide it , then they're going to continue to charge whatever they can for that area based on , you know , demand for their services in the area .

Speaker #3: And that cost will never go down unless , you know , there's just no demand for services in the area . So I think so these are long term investments we're making now .

Speaker #3: But I think they're really going to really pay off , you know , in the future . You know , for us and to continue to preserve our , you know , already industry leading low cost structure .

Speaker #3: So that's why, you know, we're really excited about what we're able to accomplish out there and be able to do it.

Speaker #3: You know, without too big of a strain on the company with our partnership there, that's funding it.

Speaker #13: Great . Thanks . And I this kind of a housekeeping item , but I did take sort of a quick look at the gathering transportation expense line .

Speaker #13: And it looked like it might have been down sequentially a bit in a in the quarter . And I just wonder if I , if I had that right and if there were any drivers behind that .

Speaker #5: Yeah, it was down sequentially. It was just over 41 million, and in the second quarter, it was just under 40 million.

Speaker #5: In the in the third quarter on . But part of that is driven by we had lower volumes sequentially as well . So you look at it on a GTC per unit basis , it was $0.36 just versus 37 last quarter .

Speaker #5: So it's really that's driven by volumes .

Speaker #3: Yeah , I would say that's probably correct . Right .

Speaker #13: Okay . Okay . Great . Thanks a lot .

Speaker #2: Thank you .

Speaker #1: Thank you . Our next question comes from Paul Diamond from Citi . Please go ahead .

Speaker #14: Morning . Thanks for taking the call . Just wanted to touch quickly on your activity allocation between Western Haynesville and the legacy acreage currently split 5050 .

Speaker #14: If you guys were to add or to any activity over time , what do you think it would come from one or the other ?

Speaker #3: Well , you know , I think that I think we we'd like to keep the four operating rigs in the western Haynesville because just because of the strategically , you know , in order to hold all the acreage that's the pace that that makes that a comfortable program .

Speaker #3: And so I think , you know , obviously we flex in the legacy area where there's no acreage considerations there , and you're kind of basing that on , you know , what's the what's the supply demand outlook , what's the price .

Speaker #3: So you know , obviously , just like last year , we flex very heavily in the legacy area . And we hope to continue just to steadily add activity to the western Haynesville as we build that up .

Speaker #3: So they're kind of , you know , on two different kind of I think we're very reactive on the legacy side to , you know , the situation .

Speaker #3: And then we want to be more, you know, steady on the Western Haynesville in order to continue to develop that asset and retain that asset.

Speaker #14: Got it. Makes perfect sense. And now that you guys have given the inventory assumptions regarding the Western Haynesville acreage, can you talk about any progression you see on DNC?

Speaker #14: It still tracking towards about 30 million per . Well and 10,000 basis , I guess . What do you guys see that going through ?

Speaker #14: Tom . What's your target longer term ?

Speaker #4: I think we're going to definitely see the cost continue to come down . You know , there's a pretty there's a pretty good spread depending on where you're drilling at on the acreage as far as you know what that DNC cost is .

Speaker #4: You know , our low you know , our low end that we've achieved so far is about 2100 bucks a foot , you know , for the stuff that's a little bit shallower , TBD .

Speaker #4: And then , you know , you're the $30 million mark or assuming like a ten K lateral , 3000 bucks a foot or a little bit higher than that .

Speaker #4: You know , if you go all the way to the other end , to the far deeper stuff , you know , probably just a little bit over that .

Speaker #4: So , you know , as far as any quarter when we're reporting , you know , it just depends on where those rigs have been and what , you know , what the TVD areas we're drilling in as far as what the cost comes out to .

Speaker #4: But we're definitely going to see the cost continue to go down . I think I think we've gotten , you know , a big chunk of it down already .

Speaker #4: And as you , you know , naturally time . I think the rate at which the costs come down probably slow a little bit , but we still see , you know , I mentioned it earlier , we still got a few things , you know , kind of coming down the pike that we're going to be trying .

Speaker #4: We think that's going to help us, you know, continue to shave days off.

Speaker #14: Understood . Thanks . Perfect sense . I'll leave it there . Thanks .

Speaker #1: Thank you . This concludes the question and answer session . I will now turn it back over to Jay Allison for closing remarks .

Speaker #2: I want to thank everybody for listening for over an hour . And you know , November the 4th is a 2025 is a great day for the company .

Speaker #2: When we can tell the stakeholders , which is you , you know , and our financial backers , which is you that , you know , we've added this giant footprint in the western Haynesville .

Speaker #2: So the debt that we have that that is the western Haynesville acreage that we have been buying , you know , it's 530,000 net acres .

Speaker #2: So but we can report on a day like today , we have over 900 million liquidity . And that's going to grow . We can report that we have , you know , 2559 Western Haynesville locations at the very beginning of time .

Speaker #2: And then the legacy locations are 917 . So we have a lot of inventory . We're not chasing inventory or we're not chasing M&A .

Speaker #2: And at the management here has been pioneered . The Haynesville Bossier shell , going back to 2008 , 17 years . So , you know , the man that's in charge of operations has been here the very first day we ever looked at at the Haynesville Bossier , which is Dan .

Speaker #2: And then you look at at managing the balance sheet , the couple divestitures that we will make and have made that just tells you that we're watching our balance sheet , which , you know , the major stockholder and everybody else wants us to do that .

Speaker #2: So I just want to thank you for for believing in the company , and we'll give you a good day's work every day .

Speaker #2: So thank you for the call .