Corey Code
Thanks, Brendan. In 2025, we will continue to focus on maximizing the returns on our invested capital to increase our free cash flow, our shareholder returns and further reduce our debt. This means we are leveraging our multi-basin portfolio and focusing 100% of our investment in our most oil and condensate rich areas. Each of these three areas is expected to generate program level after-tax returns of approximately 65% to 75%. Although the value drivers for each asset are different, they all compete for capital within our portfolio.
We expect to generate about $2.1 billion of free cash flow in 2025 and assuming commodity prices of $70 WTI and $4 NYMEX gas. This represents an increase of more than $300 million year-over-year and a near doubling of free cash flow from 2023. Our 2025 free cash flow yield of approximately 18% and a cash return yield of 10% are very competitive in today's market across both industry peers and the broader economy. As a reminder, we expect to restart our share buyback program in the quarter with first quarter free cash flow. Our enhanced capital efficiency will allow us to optimize our capital structure at a faster pace, decreasing our debt and reducing interest expense.
By year-end, we expect our total debt to be well below $5 billion making significant progress towards our $4 billion debt -- total debt target. Even though we're investing in the most oil-rich parts of our acreage, our production profile is about 50%.
And as a result, we have significant torque to higher gas prices. We've been very intentional in moving our price exposure away from weaker pricing hubs like AECO and Waha to diversified downstream markets in the US and Canada.
We have done that both physically by acquiring firm transportation out of the basin and financially with basis hedges. In 2025, about 3/4 of our natural gas will price outside of AECO and Waha. This means we stand to benefit significantly from higher gas prices, even if AECO and Waha prices remain weak. This year, for every $0.50 move in Henry Hub gas prices, we expect to generate $225 million more free cash flow. As a reminder, our price exposure gets even better in the fourth quarter with the commencement of our service on the Matterhorn pipeline in the Permian for 50 million cubic feet per day.
Access to premium resource is an essential component to generating durable returns. We recognized this early and have done a lot of work over the last few years to identify opportunities to extend our inventory runway through organic appraisal and assessment efforts and acquisitions. As Brendan highlighted earlier, we've built an enviable premium inventory position across our portfolio. As a result, we can execute our business plan and generate superior returns for our shareholders for a long time to come. We remain very pleased with the value accretion we've realized from our Permian acquisition in 2023, and we expect the same from our recent Montney acquisition.
At roughly $1 million per well location, our Montney deal will deliver strong returns and compares favorably with many of the recent deals we've seen in the broader North American market. We've been very intentional in building a high-quality portfolio with a deep inventory in each asset and in each product, and we have demonstrated that we are disciplined stewards of our shareholders' capital. I'll now turn the call over to Greg, who will speak to our 2025 guidance and operational highlights.
Gregory Givens
Thanks, Corey. Maximizing capital efficiency and free cash flow remains a primary focus for our teams in 2025. As Corey mentioned, we are focusing 100% of our investment on oil and condensate, but we also have significant free cash flow upside to stronger gas prices. About 85% of our capital will be focused on our two anchor assets, the Permian and the Montney, supported by free cash flow from the Anadarko. Our 2025 program will deliver 205,000 barrels of oil and condensate per day and total production volumes of 595,000 to 615,000 BOE per day for about $2.2 billion of capital investment.
Our full year total production will be slightly lower than if both the Montney and Uinta transactions had closed on January 1. Additionally, we've elected to reject ethane in the Anadarko for the majority of the year and we now expect higher Canadian royalties. These items will also modestly affect our volumes. The decision to reject ethane supports our realizations and the higher royalties are due to higher gas prices. So the net result is free cash flow accretive.
We expect our first quarter production to average approximately 585,000 BOE per day, including about 202,000 barrels per day of oil and condensate. The production impact from the Montney and Uinta transaction close timing is roughly 3,000 barrels per day during the quarter. Oil and condensate production will stabilize in the second quarter and remain flat through the end of the year. Our capital spend will be highest in the first quarter, largely due to transaction close timing impacts, higher completions activity in the Permian and temporary drilling activity in the Montney that we inherited from the seller. Importantly, the capital efficiency of our 2025 development program is repeatable in 2026 and beyond, allowing us to sustain approximately 205,000 barrels per day of oil and condensate production with capital investment of about $2.2 billion.
Let's shift now to the asset level development programs. In the Permian, capital efficiency and free cash generation remain the top priorities for our program as we work to drive efficiency in every aspect of our operations. Ovintiv is consistently one of the highest productivity, lowest cost operators in the basin. We recently received third-party recognition of our basin leadership from JPMorgan by being awarded the 2024 Order of Merit for Midland Basin performance. Our 2024 drilling speed averaged more than 2,000 feet per day and was roughly 18% faster than the 2023 program average.
On completions, our full year average completed feet per day was about 3,850. This was 20% faster than our 2023 program average. These cycle time improvements result in lower well costs. Our pace at our D&C cost is among the best in the industry at less than $600 per foot. The 145 gross wells we brought online in 2024 continue to paint the type curve.
This type curve was unchanged across 2024, and it remains unchanged in 2025. This year, we started with five rigs and will drop to four at the end of the first quarter to bring on 130 to 140 net wells and hold oil and condensate production at roughly 120,000 barrels per day on average for the year. Our D&C cost is expected to average $600 to $650 per foot and is about $25 per foot lower than last year. Our Permian team expects to deliver consistent year-over-year well performance from a similar number of turn in lines for less capital. Moving north to the Montney.
We are very excited to have the new Paramount assets in our portfolio, and we are working to integrate them into our business as safely and efficiently as possible. So far, the wells are performing very well as expected, and we are looking forward to delivering our first Ovintiv end-to-end design wells later in the year. As a reminder, we plan to deliver well cost savings of more than $1.5 million per well across the acquired assets by applying our industry-leading data-driven approach to drilling, completion and production operations. This approach continued to yield positive results in 2024 as we saw steady improvements in our daily average drilling and completion speed. The Montney has the lowest well cost in the portfolio, and in 2025, we expect our D&C cost to average $525 per foot.
This is about $25 per foot less than our 2024 well cost. Our 2025 3- to 4-rig program of 75 to 85 net turn-in lines, we'll see roughly 1/3 of our activity in the newly acquired acreage, with the remaining activity split between our legacy Pipestone and Cutbank ridge areas. The primary driver of value in the Montney is condensate production. And since there is a structural long-term deficit in the Western Canadian market, it should continue to trade tightly to WTI for the foreseeable future. In 2024, the average price realization for our Montney condensate was 95% of WTI.
In 2025, with the addition of the new assets, we expect to produce about 70% more condensate or about 55,000 barrels per day in total for only 40% more capital. This makes us the second largest condensate producer in the play. As Corey mentioned, we are receiving much higher prices for our Montney gas than the AECO benchmark would imply. In 2024, our average Montney gas price realization was 164% of AECO or 76% of the NYMEX benchmark. The underlying gas supply and demand fundamentals in Western Canada should continue to improve this year as LNG Canada comes online.
Moving to the Anadarko. We continue to benefit from the strong free cash flow generation from the asset, in part due to its exceptionally low base decline rate at about 16% per year. This asset is unique in providing a stable, well-priced stream of production with low operating costs and a minimal stay-flat capital requirement. In 2024, the team continued to make significant progress in lowering well costs by focusing on drilling speed, maximizing lateral length, minimizing casing strings and maximizing the number of wells per pad. They've taken nearly $100 per foot out of our average D&C cost, and are set to deliver an average of about $550 per foot in 2025, a reduction of $100 per foot year-over-year.
Our efforts in the play have not gone unnoticed as our Anadarko asset also recently received the 2024 Order of Merit from JPMorgan. We plan to run an average of 1.5 rigs in the play this year, delivering 25 to 35 wells. This will essentially hold our oil and condensate volumes at around 30,000 barrels per day on average for the year. I'll now turn the call back to Brendan.
Brendan McCracken
Thanks, Greg. In closing, we continue to deliver outstanding results. We're focused on maximizing the profitability of our business, generating significant free cash and generating -- and maintaining our strong balance sheet. Our focus on building premium inventory depth, execution excellence, disciplined capital allocation and driving profitability have positioned our business to thrive on the road ahead. This concludes our prepared remarks.
Operator
Gabe Daoud at TD Cowen
Gabriel Daoud
Thanks. Hey, morning, everyone. Thanks for taking my questions. Brendan, I was hoping if you could maybe first start with Montney versus Permian, you highlighted pretty attractive returns across the entire portfolio. But from an A&D standpoint, where -- given where acreage and location values are rising to in the Midland. Would you say maybe your bias from here would be to add more in the Montney versus Permian if there was a need to add some more inventory?
Brendan McCracken
Yes, Gabe, thanks for the questions. I guess what I'd say at a high level before maybe making a comment on the relative market and the two assets for acquisitions. What I'd say at a high level is it feels really hard to beat what we've done so far. This has been a multiyear effort to assemble the portfolio and really I feel like what we're representing today is a new level of portfolio and inventory depth and quality for our investors. And we have a ton of confidence in that portfolio being able to generate the free cash flow that we pointed to for 2025 for a long time to come.
And so it feels really difficult, I guess, you'd call it a high bar to beat that today. And so in general, our view is anything we would do would be coming from a position of strength, and we're excited about what we've done over the last several years. In terms of the relative -- I mean, you've hit it, there's just a massive arbitrage between the 2. And at the same time, as we were able to do our transaction for right around $1 million in undeveloped location, we've seen prints in the Permian for well north of that. So we think that's value to our shareholders that we're uniquely positioned to be able to access and create for them.
Gabriel Daoud
Thanks, Brendan. That's really helpful. And then I guess just as a follow-up, you mentioned on the slide, the Permian and Montney oil powerhouse. So I guess, good question then off the back of that would just be how does Anadarko fit into the portfolio longer term. Any updated thoughts there?
Brendan McCracken
Yeah, and absolutely, if you look at where 85%, 90% of our capital is going into the Permian and the Montney, so that is a big part of how we're running the business and prosecuting the strategy and we put ourselves in a place here. We've got close to 15 years of premium oil inventory in the Permian, closer to 20% of oil inventory in the Montney and then over a decade in the Anadarko. And so we really like the role that the Anadarko is filling for us. It's a really valuable asset.
And what's really unique about it, and we've highlighted it a couple of times but perhaps even underappreciated is the low decline nature of that play. And what that does is it supercharges the free cash that it's generating. So at a 16% base decline, that means we don't have to spend very much capital in there to level that asset out around the 30,000 barrel a day mark this year. It will start a little lower in Q1 and then build to that 30%. But but we're really excited about the role that the Anadarko is playing.
I would also highlight that's a spot where our type curves are up year-over-year. And the team has done a great job of getting well cost down and type curves up, which boost returns. And so whether we're running a rig in the Anadarko or a rig in the Permian or the Montney, they're delivering the same financial outcome for the business, which is very important from a capital allocation perspective.
Gabriel Daoud
Yeah, no, for sure, it's good to see you. Awesome. Thanks, Brandon.
Operator
Doug Leggate at Wolfe Research.
Douglas George Blyth Leggate
It's a [Mechem] for for Doug this morning, he is unavailable in this particular time. My first question would be regarding your net debt target, you have a long-term target of $4 billion. You guys reduced by $3.23 million for the past quarter. I guess what do you kind of project being your net debt target by end of 2025. If you can give me any color on that and how you get to that number?
Brendan McCracken
Yes, absolutely. So I think what we've got in the material is we're going to get it well underneath the $5 billion mark by the end of this year. If you look at prices on the screen today, be in that $4.6 million, $4.7 million range by the end of the year, which we're really excited about because that now puts us within spitting distance to get into that 2020 -- or getting to that $4 billion target in 2026. So really excited about the trajectory they were on there. And we've pointed in the materials as well, we'll be resuming buybacks in the second quarter here following the pause off the back of the acquisition in the Montney and really excited that we've been able to kind of reduce that incremental debt that we took on with the acquisition very quickly.
and get back into the buyback market because we're excited about buying shares at this level.
Operator
Arun Jayaram at JPMorgan.
Arun Jayaram
Brendan, you provided an updated inventory analysis across three of your core basins, which points to well into the double digits in terms of inventory depth on the oil side and beyond that on the gas side. Brendan, what do you think this does for you from a strategic standpoint, just having that durable inventory position as we think about future A&D and just other opportunities as we look forward, obviously, you highlighted maybe $2 billion of free cash flow, a little bit over that at strip and maybe the potential for that to continue over time.
Brendan McCracken
Yes, Arun, I love the question. I think it really puts us into a new category here, and that's what we're trying to impress is the confidence that on behalf of our shareholders, we've built that inventory position. and it gives us the confidence in that free cash generation and the durability of it, which is the important point that you're flagging in addition to the inventory depth and quality, which we think is really enviable. We're also seeing lower capital in the business and lower cash costs, which means higher profitability and higher free cash that's coming with that. So it's really a combined effect of providing our shareholders the confidence in that inventory to be able to generate these returns durably and then just continuing to use our efficiency gains, both on the capital and the cash cost side to just drive free cash flow over time.
And then like I say, we're getting a great cash flow per share boost with the buybacks and the value we're shifting to the equity holder by reducing debt. So it's really kind of an all-of-the-above attack. And you also -- I think you hinted at or asked in your question of how that frames it up in terms of A&D thoughts. And I would just say that this makes an already high bar even higher, given what we've been able to do with the portfolio.
Arun Jayaram
Great to hear. Maybe my follow-up, if there's one incoming question we've gotten just on the regulatory macro picture is just maybe the impact of potential Trump tariffs on Canada I was wondering if you've done some analysis on that and just provide some -- just some general thoughts because I know it's a pretty complicated question just given where we don't have a ton of details here, but I was wondering, Brendan and Corey, if you can maybe help us frame the potential impact.
Brendan McCracken
Yes, absolutely. Look, the steering we give you at this point, we anticipate a pretty modest impact to our business. And let me kind of dig in and describe it a little bit more. as you flagged, there's still a fair bit of uncertainty about timing. Is there going to be any exceptions?
What are the magnitude of the impacts and how are they going to be expressed in the market? And so what we've done, as you might expect, sort of a ranging type scenario from sort of a more moderate tariff scenario to a more extreme tariff scenario. And even in the more extreme pictures that we contained it is a very modest impact to our cash flow in '25. Maybe I'll just flag because it might be helpful for folks to understand the different places that we would see tariffs potentially impacting our business. we'd expect to see something in the supply chain.
We already have this steel and aluminum tariffs in place. So that largely shows up as an OCTG impact. And remember here, we source all of our OCTG domestically in the US, but there could be some bleed through to domestic prices because of the tariffs on international imports. So we've been proactive in purchasing and pricing a significant part of that 2025 supply chain already. But we don't anticipate that to be a severe effect.
On the gas side, of course, we export gas into Chicago and into the US West Coast. And so there could be impacts there. which also could see some bleed through into the AECO and the down markets. Again, all of this conditional on are the reciprocal tariffs for the gas that Canada import, there is a range.
And then, of course, all of our condensate we sell that domestically within Canada. And then finally, the sort of counterbalance point is around foreign exchange. And I'd say the consensus view is that tariffs on Canadian imports into the US would strengthen the US dollar relative to the Canadian dollar.
And for our business, a lower Canadian dollar is favorable for free cash generation. So you kind of put all those different categories together and their net-net scenarios suggest pretty neutral in terms of an impact to our 2025 cash flows, even that more extreme tariff scenario picture that we can paint today. So watching it closely. Clearly, there's a lot of dynamics, but don't anticipate it being a significant impact to '25 cash flows.
Arun Jayaram
Thanks, Brenda.
Brendan McCracken
Yeah, thanks, Arun.
Operator
Neil Dingman at Truest Securities. Please go ahead.
Neal Dingmann
Morning guys, thanks for the time. Right, my question maybe for you or Greg, just again, the ops efficiencies are notable. I'm just wondering, when you look at your guide and expectations for this year, I'm just wondering, what are you all thinking sort of service cost versus continued operational efficiencies. It looks like you might have a benefit of both. And I'm just wondering how Greg or yourself are sort of viewing that for at least the remainder of this year.
Brendan McCracken
Yes. Neal, absolutely. So I'm going to kick it to Greg. High level, we've got about a low single-digit deflation built into the 2025 program, and -- but the bulk of the gains are true efficiency gains, but I'll kick it to Greg to maybe just highlight a few of the really key ones.
Gregory Givens
Yes. Thanks for the question, Neal. I'm just continue to be impressed with our teams and what they're able to accomplish. 2024 was the fastest year we've ever had in drilling and completion, both in the Permian and in Canada. Maybe just a couple of stats.
I mean, 30 of the 35 fastest wells we've ever drilled in the Permian were drilled in 2024. So the team just continues to get significantly better. And that's what allowed us to continue to drop rig count. We're constantly trying to match up the rigs with the right number of frac crews to be as efficient as possible and take white space off the calendar. Last year, we had six rigs running in the Permian, ended up dropping to five late in the year.
And then as I mentioned in my prepared remarks, we'll be dropping to four rigs here at the end of the first quarter. And all of that is really just trying to sync up the right amount of frac activity. Something that was really impressive. If you were to take the four rigs that we're planning on running for the majority of this year and pair that with 1 trimul-frac crew. We could do 110 to 120 wells with that set up.
So almost our full program with what we think today could be accomplished with four rigs and 1 trimul-frac crew with the efficiencies we continue to see I wouldn't be surprised if that becomes the norm for us going forward. So just continue to be really proud of the teams and how fast they're going. But of course, then we believe strongly in level-loaded programs in a balanced schedule. So as we get these efficiencies that bring more activity into the year, well then some of those savings will be reallocated towards the end of the year to continue that level loaded program. But just continue to see great performance, and we think we're going to see even more here in '25.
Neal Dingmann
Great. And just one last thing, you guys have been busy on the M&A, obviously, with the Montney. I'm just wondering, Brendan, when you see for the Montney foot hit now in your Permian footprint. Is there still a fair amount of white space that you can fill in. Just wondering on smaller deals.
Thank you.
Brendan McCracken
Yes, Neal, you're a little muscle there, but I think your question was just on are we going to continue to try and fill in some white space in the Permian and the Montney on map. And I just sort of -- yes. Okay. I heard that right. Good.
Yes. I think the answer there is kind of similar to what I described before. It's -- we're taking a high bar and raising it even higher in terms of allocating capital towards acquisitions, given the success we've had over the last several years and given the inventory depth and quality that we've created. So I think teams are going to be continuing to do a lot of work on swaps and coring up so that we can drill long laterals on the footprint that we've already got. I would expect that to continue at a pace.
And -- but pretty disciplined around how we're thinking about go-forward bolt-ons and acquisitions.
Neal Dingmann
Thank you.
Brendan McCracken
Yeah, great, thanks you.
Operator
Kalei Akamine of Bank of America
Kaleinoheaokealaula Akamine
Hey, good morning guys. Maybe this question is for Corey. So we appreciate the free cash flow yield sensitivity at 18%. There's, kind of a delta versus the street as you guys were putting that analysis together, where did you find street numbers to be insufficient?
Brendan McCracken
Yeah, I'll flip that over to Corey Clay. Thanks.
Corey Code
Yes. I mean we did take a little bit more time to highlight the leverage to natural gas. And I think if you go back even over the last year or 2, we've talked a lot about our oil portfolio. So just reminding people of the significant natural gas exposure that we have. But what you've heard through the call, and if you look at some of the actual results, we've had good not just capital efficiency, but all of our various elements of cost, I think, have outperformed.
So it's a bit of a combination depending on which analyst you look at, whether it's realized price or on the cost side. But I guess the short answer is probably multiple factors contributing to that outperformance on free cash flow.
Brendan McCracken
And I did think -- I would add -- I would just add, Kalei, sorry, this is Brendan. Again, I would just add, overnight with the disclosure that we put out, the team did have some good conversations with a few of the analysts where there were some models that just had some bus in them, and we're able to get those cleaned up and match the free cash projections that we've put out there.
Kaleinoheaokealaula Akamine
Sounds good. Kind of shifting over to the Montney here, looking at your GP&T expense, it's higher than peers in basin. Can you kind of remind us why it's different? Is it related to ownership of GT assets? And if so, would you ever consider bringing that fixed cost in-house.
Brendan McCracken
Yes, Kalei. The -- you've hit on it exactly. There's a -- generally speaking, in the Montney, a mixed bag of ownership of midstream and non ownership of midstream and just the way our midstream has been built out over the decades, it is largely third-party owned. So our realizations on the cost side reflect that. And as far as looking at bringing things in-house, I think we're always looking at every opportunity we can to enhance profitability, but we'd have to weigh that against the cost, of course, of that acquisition.
Kaleinoheaokealaula Akamine
Got it thanks Breton.
Brendan McCracken
Yeah, you bet.
Operator
Greta Dreevy at Goldman Sachs.
Greta Drefke
Morning and thank you for taking my question.Thinking about risk management through volatility, would you characterize a sufficient proportion of your production is covered with your current hedge book? Are you seeking to further reduce unhedged exposure, either in the oil or gas portfolio from here?
Thank you.
Brendan McCracken
Absolutely, we've been running about a 25% hedge book and using large three ways to put that risk management in place so that we can retain as much you're while creating a floor. And really how we think about it is we want to be able to withstand a long period, call it, 12 months of pretty low commodity prices, call it, sort of the $40 on TI and $2 on NYMEX. And that -- that's been the strategy we've been following while we've been delevering. And what we've signaled all the way along, this continues to be the case, is that as we get that debt down, the need to have that hedge book can shrink even further. So I do think as we look out into 2016, we'll continue to be following that hedge strategy.
But then thereafter, we can continue to look to drag that down as we get the leverage back into the target range.
Great. And then also for my second question, the results from trimul-frac have been very compelling in 2024. July 25 outlook for about 75% of Permian operations utilizing trimul-frac. Do you see much upside to that estimate in 2025 or 2026 or would you consider 75% closer to the optimal proportion of operations?
Brendan McCracken
Yes, I think we'll continue to see it inch up with time. That's been the sort of track record so far for the team. And I don't know, Greg, if you'd have any other comments there?
Gregory Givens
Yes. I think over time, that will continue to come up. The only thing keeping us from doing all of our wells with trimul-frac are just physical location physical limitations on the ground. We have situations where you don't have six wells on a pad or you have six wells that are separated by a road or some other physical thing that prevents you from some frac in all six of those at the same time. But we'll continue to inch that up.
We continue to be very happy with the results we're getting from trimul-frac. That's what's allowing us to -- we think, complete more feet per day than anybody in the industry out there. And so we'll continue to work on that.
Greta Drefke
Great thank you.
Brendan McCracken
Thanks Greta.
Operator
Kevin McCurdy at Pickering Energy Partners.
Hey, good morning and thank you for taking my questions. My two questions are going to focus on a little bit on gas. I appreciate the details on the free cash flow sensitivity to gas prices on slide 8, and we would agree that you have one of the higher sensitivities among oilier companies. But I wanted to ask about the operational sensitivities. Is there a price that would you shift capital to the gassier assets or increase overall company activity?
Brendan McCracken
Yes, Kevin, great question. It's actually a really interesting one. And we've tried to flag for folks, but I think it's meaningful. When you drill a gas well, you get a whole bunch of -- when you drill an oil well, you get a whole bunch of gas with it. And when you drill a gas well, you get 0 oil with it.
And so it actually is an asymmetrical capital allocation choice from a value perspective. So what we really like, given where prices and the fundamentals are today is we like being in maintenance mode. We continue to believe the right allocation of excess free cash flow is to the buybacks and not to growth. And that's because we're gathering a better cash flow per share outcome from buying those shares back than we could get by investing that for growth in the business. And so that's sort of first off.
And then when you look at the decision between gas and oil, we really like the allocation to drilling oil wells and then the associated gas upside comes along with it as opposed to saying, "Oh, no, we're going to allocate directly to dry gas." So obviously, there can be a breaking point depending on the fundamentals. But with today's prices, we continue to favor allocating our capital to oil and getting the gas as an associated upside.
I appreciate that response. And for a follow-up, you've done a really good job of diversifying your AECO exposure. But do you have any view on how that market develops, hopefully, as more demand comes online locally?
Brendan McCracken
Yes. I think our view has been pretty consistent there, which is we're going to see some benefit from the additional a little over two Bcf a day of offtake off the West Coast. And there's been some color already this quarter from some of the operators and some of the participant companies on time line there, which is coming up this summer for the first loads, which is exciting. But our view has been that it's going to be probably relatively transient as opposed to a structural reset of AECO pricing. And so our strategy has been to continue to diversify gas away from the AECO basin.
And I think that will kind of continue. We inherited a couple of hundred million a day of additional AECO exposure with the Montney acquisition. So that's likely to be something you'll see us chip away at between exploring LNG options for that gas, exploring getting more gas into the markets we're already serving the West Coast in Chicago but also some of this data center demand optionality that's showing up where there's -- we've been in a lot of conversations with a lot of interested counterparties there, which is really exciting. And we think we're in a differentiated place in Western Canada to be a gas provider of choice for some of those projects, whether it's data center or petchem because of our investment-grade status and because of our deep gas resource in the basin, which can give a counterparty a lot of confidence, both financially and subsurface in the resource.
Oh very interesting thank you.
Brendan McCracken
Yeah, thank you, Kevin.
Operator
Dennis Fong at CIBC World Markets
Dennis Fong
Maybe the first one is to carry along with the last kind of train of thought there. You kind of mentioned some opportunities to, I guess, I don't want to necessarily lock in a longer term or longer duration contract or pricing, but can you describe -- I know historically, there's been a few characteristics of these types of whether the LNG contract or whatnot that you've wanted to ensure if that was an attractive option for selling the debt. Can you remind us as to what you'd be looking for in that type of a situation?
Brendan McCracken
Yes, Dennis, I think the first thing to start with is we're interested in having a portfolio of diversification here. We like the idea of not putting all the eggs in 1 basket, so to speak. And you can see that already. that we've made with getting to diversified downstream markets today. And so I think going forward, what you should expect from us is a portfolio and our vision is for that portfolio to have a mix of LNG and a mix of local incremental demand, whether it's, like I said, data centers or pet chem opportunities.
And so I think we'll see how those deals come together. But what we really like about that portfolio is it not only provides the upside for our realizations, but helps us manage risk. And one of the things that's really kind of been a focus point for us is to not wind up signing up for a long-term transportation and processing contract that's fixed into an uncertain market. And so that's been the focus of our commercial team is to make sure we find ways to manage that diversification risk and not wind up with a long-term service agreement that is underwater for long periods of time.
Dennis Fong
Great. I appreciate that color. I wanted to shift gears a little bit more into the cost side. You've obviously made a lot of progress on operations, obviously, with rate of drilling, completion efficiency, the use of trimul-frac. I wanted to go into kind of supply chain management.
I know that's something that you guys have also been a leader of obviously, with risk around tariffs and so forth, how are you maybe managing around drill pipe, obviously, completions material well tubulars and so forth? Can you remind us as to how your supply chain management group is optimizing efficiencies and maybe trying to manage the risk around trade and so forth?
Brendan McCracken
Yes. Great question, Dennis. And that is piece that we've been a pretty sophisticated player in for quite a while. And I would tell you, a lot of the supply chain work that we've been doing over the last couple of years to be prepared for geopolitical risk upsets in the supply chain. It looks to be paying off as we now encounter these tariff uncertainties.
And so we've mentioned before and Greg might want to have some comments, too, on we're sort of fairly well covered on OCTG for this year. And we've also thoroughly reviewed our supply chain for for where are the other pinch points, whether it's pipe sales and fittings or chips or any of the pieces and parts that we utilize every day to make sure that we don't wind up into a sole supplier type dynamic and see a disruption or see a big tariff impact. But Greg, if you want to add anything feel free.
Gregory Givens
Yes. Thanks for the question. And the team has done a really good job over the last several years of digging deep into our supply chains to make sure we had security of supply. That was our initial concern. So we've traced all of our not only initial but secondary supply chains of our providers all the way back to where the products are being manufactured and to guarantee guarantee security of supply, and more recently, that then applies to making sure we can not only get what we need, but also get it at the right price to avoid potential tariffs.
And so this year, we've secured predominantly all of our tubulars that we're going to need for the year. most of those are done domestically, but so we've locked in pricing and then locked in supply. A lot of the other smaller items we're working through sure we've got access to those at fair prices as well. So as Brendan mentioned in the previous question, any tariffs or other volatility should be relatively minor as they flow through to our overall capital cost.
Dennis Fong
Great, really appreciate that colour. Thank you. I'll turn it back.
Operator
At this time, we have completed the question-and-answer session. And I will turn the call back over to Mr. Berheist.
Jason Berheist
Thanks, Joanna, and thank you, everyone, for joining us this morning. Our call is now complete.
Operator
Ladies and gentlemen, this concludes your conference call for today. We thank you for participating and we ask that you please disconnect your lines.
