Good day, and welcome to the California Resources Corporation Fourth Quarter Earnings Conference Call. All participants will be in listen-only mode. Should you need assistance, please signal a conference specialist by pressing the star key followed by zero. After today's presentation, there will be an opportunity to ask questions. To ask a question, you may press star then one on a touch-tone phone. To withdraw your question, please press star then two. Please note this event is being recorded. Now, I would like to turn the conference over to Joanna Park. Please, Joanna, go ahead.
Welcome to California Resources Corporation's fourth quarter 2022 conference call. Participating on today's call are Mark McFarland, President and Chief Executive Officer, Francisco Leon, Executive Vice President and Chief Financial Officer, as well as the entire executive committee. I'd like to highlight that we have provided slides on our investor relations section of our website, www.crc.com. These slides provide additional information into our operations and fourth quarter results.
We have also provided information reconciling non-GAAP financial measures discussed to the most directly comparable GAAP financial measures on our website as well as in our earnings release. Today, we are making some forward-looking statements based on current expectations. Actual results could differ due to factors described in our earnings release and in our 10-K and other periodic SEC filings. As a reminder, we have allotted additional time for Q&A at the end of our prepared remarks. We ask that participants limit their questions to one primary and one follow-up. With that, I'll now turn the call over to Mac.
Well, great. Thank you, Joanna. Good morning, everyone. Thank you for joining us today. Over the past two-plus years, following the company's emergence from its financial restructuring, we have evolved CRC into an enterprise focused on generating the highest cash flow from our assets and returning that cash to shareholders. Case in point, in 2022, we returned 120% of free cash flow to shareholders through share repurchases and dividends. We bought back 14% of the company's outstanding shares since our emergence in late 2020. We also saw a tremendous opportunity for carbon management and have built a solid business around that. As any focused company should do, we continue to evolve.
As we look forward to 2023 and beyond, we are announcing a strategic realignment of the company's business operations and structure to adapt to current circumstances and build on our strong momentum. As I have said before, and to say it simply, we are focused on generating the highest cash flow per share possible from our E&P business so we can return that cash to shareholders. Another case in point, if you take 2022 free cash flow of $311 million and the average fully diluted shares outstanding of 77.6 million during the year, we delivered $4 of free cash flow per share in 2022.
If you take the midpoint of our 2023 guidance of $385 million of free cash flow and the fully diluted shares outstanding of 73.6 million at the end of January, we would expect to deliver $5.23 of free cash flow per share in 2023. That would be roughly a 30% increase in cash flow per share, and that is before we buy any more shares back in 2023, which would drive the results even higher. That is the benefit of our low decline assets and the toggles we have available to us in the business. In connection with this strategic alignment, we are announcing management and board changes to support the eventual separation of our E&P and carbon management businesses.
We are also cutting costs to match activity levels, and we plan to increase our financial flexibility to accelerate shareholder returns. By taking these steps, we believe we can create a different kind of energy company and drive cash flow per share growth. With the revised corporate structure, Francisco Leon will succeed me as CEO, and I will step back from the day-to-day management role. I will continue to serve on the board of CRC and will chair the newly formed board of our Carbon TerraVault subsidiary, which will be devoted to overseeing the continued growth of the carbon management business. Two existing CRC non-executive directors, Andrew Bremner and James Chapman, will also serve on this subsidiary board.
Together, we will provide the business with insight into the commercialization of new technologies, provide expertise in corporate and financial structuring, as well as provide knowledge relevant to early movers for carbon capture and storage in California. I've had the tremendous opportunity to work with the great people of CRC and forge many great friendships. Having spent more than 2 years working with Francisco side by side, I am confident he is the right person to lead us at this exciting time in going forward. I'll now turn it over to Francisco to share more details on the steps we're taking to position our business for success. Francisco.
Thanks, Mac, and thank you everyone for joining the call. I will focus my comments on the actions we're taking to enhance value and deliver stronger shareholder returns and to maximize cash flow per share of the business. First, we have provided detailed analysis about our 2022 quarterly and yearly financial and operational results, and also our 2023 guidance in the attachments to our earnings release and in our slide deck. I will refer you to those documents for that information rather than cover them on this call.
As you will see, 2022 year-end financial results were very strong, with over $300 million of free cash flow helping showcase our resilient and valuable portfolio of assets. As we delivered on all of our 2022 priorities and look at what's in front of us in the next chapter, we must continue to evolve. Here's our plan for 2023. We're going to focus our development and drilling plan on developing the highest returning projects with permits in hand. That, combined with well servicing and downhole maintenance, will help reduce our base production declines. We will do this by reducing capital investment to 1.5 rigs, which is based on permits in hand in the Wilmington field for high rate of return projects with short paybacks.
This constitutes a run rate E&P CapEx program of $155 million per annum, as demonstrated with our 2023 program, as you can see on slide 10 of our presentation. We're also adding OpEx dollars to downhole maintenance, increasing our rig maintenance count by 6 - 38, which combined with our capital program, we expect to deliver a 5%-7% total decline for the company.
We have a backlog of about 1,000 wells that we can go after and return to service and return to engineering that allow us to make high-impact investments with very little incremental operating expenditure dollars. Given reduced activity levels across our E&P business, we're also looking to reduce all other non-energy operating costs and Adjusted E&P corporate and other G&A costs by 5%-10% by year-end, aligning our costs to activity level.
We have successfully implemented similar strategies in the past and believe the company is well positioned to identify and achieve additional cost reductions while maintaining the high operational and safety standards that CRC has achieved over the years. In addition to the revisions to our operating plan, we're also pursuing ways to increase our financial flexibility to bolster the company's ongoing shareholder return program and enable a potential future separation of the company.
To help achieve this financial flexibility, we intend to refinance the $600 million high-yield notes and extend or replace our RBL. Clearly, having Carbon TerraVault operate on a standalone basis will broaden capital sourcing options for that business. Our continued focus on cost and our ability to maintain production due to the high quality of our assets gives us confidence in our cash flow projections.
As such, CRC's board has authorized a 30% increase to the share repurchase program for a total of $1.1 billion, with $640 million remaining of dry powder. With this plan in 2023, we expect to generate $455 million of E&P free cash flow and total corporate after-tax free cash flow of $385 million. Of this, we intend to return 100% to shareholders in 2023, continuing our track record of returning more than 100% of cash to shareholders and maximizing cash flow per share. If market conditions persist in 2024 and beyond, we will repeat this plan.
If we assume a one and a half rig count going forward, we are confident that we can lower our capital plan of approximately $155 million of drilling and completion capital. We can make the appropriate reductions to our cost structure that we expect will ensure that we deliver improving operating and financial metrics on a per-share basis. I am really excited about the future of CRC and look forward to working with our talented team to take the steps to separate our quality, low decline, low carbon intensity, and high cash flow-generating E&P business and our California-leading Carbon TerraVault, which will help unlock the company's full potential for delivering value to shareholders.
I want to take a moment to thank Mac for his leadership these last two years and look forward to working with him to accelerate the growth of our carbon management business. Thank you for your interest in CRC, and thank you for joining us on the call today. We'll now open the line for questions. Operator?
Thank you. We will now begin the question-and-answer session. To ask a question, you may press star then one on your telephone keypad. If you are using a speakerphone, please pick up your handset before pressing the keys. To withdraw your question, please press star then two. At this time, we'll pause momentarily to assemble our roster. Our first question comes from Scott Hanold from RBC Capital. Scott, please go ahead.
Thank you, appreciate it. Francisco, congrats on the promotion. Well re-deserved a nd Mac, you know, you know, congrats and on all your leadership to this point and in the future. Good to see those moves in place. My first question is gonna be around permitting, and it may be a little bit of a multifaceted question, but let me give it a shot here.
Can you give us a sense, you know, the decision to go to, you know, this 1.5 rig count and, you know, lower activity pace. You know, has your view changed on the litigation that's ongoing in Kern County? Has that changed that drove that opinion? You know, could you also give us a sense of like, how many total permits do you have in hand and in what basins? To give us a sense of like how much you know, runway you have, outside of 2023?
Hey, Scott. Thanks for your nice words and the question. You know, when we issued the 8-K a few weeks ago around the appeal process in Kern County, and I think what we were looking to do today after getting feedback from all of our investors was to showcase what the plan would be on a go-forward basis, and that's what we did today. The 1.5 rigs has effectively all concentrated in the Wilmington field. As you know, we operate in three field, three basins, the Sacramento Basin, Kern County, San Joaquin Basin, and then the L.A. Basin. The litigation is only around Kern County, so that gives us optionality to go to these other two basins.
We're focusing activity in the L.A. Basin, in the Wilmington field, and we have a lot of runway there. It's kind of independent process to get permits. Nothing has really changed around the appeal process. What we said is, okay, obviously we can get some good news there, and we're also working on alternative plans around individual fields, CEQA, right? Remember, this is a Kern County-wide permitting process, but we can still go to individual fields to get those permits replaced. We're working through that, and nothing's really changed.
What we wanted to provide was a view to our shareholders that of what we would do in case the appeal process continues and drags on. To us, there's upside to the story. We already communicated, where we saw the impact, and we think we can deliver 1.5 rigs, on a go-forward basis if the appeal process continues to drag on.
Okay. appreciate all that color. as my follow-up question, I mean, there's a lot of, you know, different questions I could ask you, but I obviously have to talk about the strategic kind of repositioning of the company. could you give us, you know, your view of, you know, the vision for what you think is gonna transpire and, you know, how you get there and the timeline? It sounds like you're separating the two businesses. Do you have separate management teams? you know, is the path to separation first to get the EPA Class VI permit in hand and then, you know, go down that path? Or is it a little bit more of a longer or shorter process?
No, Scott. Yeah, we haven't put out a specific timeline, but we, Mark McFarland and I and other members of the team, we built together Carbon TerraVault. We think it's a fantastic business. Very excited about that. You know, as we talk to investors, they wanna understand better. Right now, it's all integrated, all consolidated. They wanna understand better how each of the two businesses is advancing on a go-forward basis.
We wanted to start the beginning is to take the steps of Mark McFarland moving back to the board, but then having much more direct oversight into Carbon TerraVault by creating a board seat at the sub level. That allows him to have that oversight and continue to help from that standpoint. We're also looking at cost of capital options and looking at flexibility of running the business and making sure we have the right people and the right assets allocated to the two businesses that, at the end of the day, we think should be run separately. It's gonna take some time to get there. We were taking all the initial steps, and it starts with the messaging today around our structuring decisions. Maybe Mac has a few additional thoughts to share about Carbon TerraVault.
Well, yeah. Hey, Scott. Good morning or good afternoon. Look, I'm really excited about chairing the Carbon TerraVault subsidiary board and helping advance that. You're exactly right. Look, we have a vision that these two businesses over time need to be run and potentially separated. That will mature over time. This is just the first step of many. As you look to stand up a business, it takes a lot of work, but we're ready to meet that challenge, and I'm excited about it.
It is not dependent upon what happens with respect to different commercial you know, commercialization activities of Class VI or any of that. It's just over time, there's a lot of connective tissue, if you will, between the two businesses. We're gonna start looking at how do we effectuate change into an eventual separation down the road.
Okay. Okay, understood. I would assume the financials are going to be separated going forward. Is that going to happen or we see that pretty soon here?
Yeah, that's the intent to start giving much more visibility into the cost structure and the financials of the business in the near future.
Appreciate it. Thank you.
Our next question comes from Nate Pendleton from Stifel. Nate, please go ahead.
Good morning and congratulations, Francisco.
Thanks, Nate.
For my first question, regarding the recent announcement about your planned direct air capture hub, can you speak to how you view the potential for DAC compared to point source capture projects, from an economic and an opportunity perspective for Carbon TerraVault going forward?
Yeah, absolutely, Nate. We're very excited about the DAC consortium, and I'm gonna let Chris Gould, who's the architect of that vision, answer the question. Go ahead, Chris.
Hey, good morning, Nate. Yeah, happy to share that. The value proposition for direct air capture obviously starts with this DOE opportunity, right? It's a $3.5 billion funding opportunity that came out of the DOE for a technology that's at the beginning stages of maturing and coming down the cost curve. Much like wind and solar did in the past, we see the opportunity for direct air capture to have a very long runway building over time. It's estimated to be in the neighborhood of 15%-20% of the requirements worldwide and in California for emissions removals, actually. It's a substantial, significant emissions opportunity for CTV.
The state has set, to my knowledge, the leading target for direct air capture of north of 60 million tons per annum through 2045, and that's the evidence of the size and scale of it. We think it's a great opportunity for us to come in with the DOE funding and progress. You'll know that the incentives for direct air capture from 45Q are $180 per ton, so they are the largest incentives in that program. In addition to that, California is home to the largest concentration of carbon direct removal credits from Fortune 100 companies and tech companies that are very eager to purchase these sorts of instruments to offset and fulfill their net zero goals.
Thanks. That's really helpful.
Hey, Nate. It's Mac. Just a couple of things. First of all, you know, on the economics, look, if you look at the revenues, they're the highest that, you know, are going through 45Q, as Chris just said, to something like Carbon TerraVault or the credits, if you will, that we count as revenues, but a technical issue there. Any event, there are more credits that go to through 45Q to DAC than there are to other forms of carbon capture. That's important, but it's not enough because as you know, the you know, we're talking about parts per million capturing, so very low concentration out of the air and sequestering.
That said, we're really excited about this and the DOE work and the consortium that Chris has put together, and we're advancing and responding to the DOE's request. We hope to put one of the DAC hubs here in California through that consortium. It's very, very exciting. I mean, I will tell you that the breadth and the participants of our DAC consortium are far greater than I ever expected. Chris has done a tremendous job getting it there.
The response to it, whether it be through the government, local communities, colleges, all the rest, has been beyond expectation. You know, I'm just looking forward to keeping the momentum going here on what Chris has built, and it's really a tremendous opportunity for us.
Absolutely. Thanks for that color. As my follow-up, staying on the carbon management business for a moment, can you provide any color around conversations or how they're progressing with future CDMA agreements?
Yeah, Nate, I mean, as you saw, we've been out the gate with two CDMAs with Lone Cypress and Grannus, excited about blue hydrogen, blue ammonia. Then came the DAC hub, and, you know, it's just, you know, in a matter of a couple of months, we've been able to share some of those developments around more of the greenfield projects. We're talking to all types of emitters.
We're confident we have the leading position in the state and the several million tons of permits in the queue. We're getting a lot of deal flow. Maybe we can, I'll turn it to Jay Bys who's leading the discussions on the emitter front, see if he wants to add any more color.
Thanks, Francisco. No, I think Nate, Francisco captured it. You know, we're continuing conversations both with existing emitters and greenfield emitters. It's actually a pretty exciting time to be in the business. Just as with the arrangements we've announced to date, we'll announce subsequent arrangements really when we've gotten to detailed parameters and terms. We're just trying to be responsible in that regard. I think the market's gonna be pleased.
Yeah. I guess the last point I'll raise, you know, existing emitters, we have to go through the price discovery. That takes time at the end of the day. Our conditions in California are very different than the rest of the country around CCS and the incentives that we receive. There's really no model. We're building it. We're having these commercial negotiations, but that will take time, but we're still focused on point source emissions.
We're also very focused on our own emissions through CalCapture. Made some really good progress on our FEED studies. I think that's gonna be a really viable project. More to come, but we're, like I said, we're talking to a lot of emitters and seeing a lot of deal flow and just a matter of time before we can talk about incremental activity there.
Great. Thanks for taking my questions.
Thanks, Nate.
We now have a question from Leo Mariani from Roth MKM. Leo, please go ahead.
Yeah. Hi, everybody. Just wanted to follow up on the kind of future of the E&P business here. You guys are obviously talking about this kind of, you know, 5%-7%, you know, type of decline in the production. You're gonna do your best to stave it off. I just wanted to get a little bit more information around that. Do you see this as more of a long-term, you know, strategy for the company, given that California hasn't been all that friendly to oil and gas companies?
You made a comment in your prepared remarks that this is the plan for 2023, but if market conditions persist, perhaps this continues. Do you see this as more of a likely long-term strategy or for whatever reason, the permitting situation finally gets straightened out? Would you guys potentially go back to kind of holding production flat, in the next handful of years, I think which was the original plan?
Leo. Yeah. So yeah, we're not gonna get into kind of guidance for out years beyond 2023. What I will say is, I think the market was able to see how we perform in 2022, when we ran four rigs, kept production flat. That model, I think it's clear to the market. What's maybe not as clear and what we're hoping to highlight today is in this new, you know, the new challenge from the appeal process in terms of how we would manage the company going forward, right? Really wanna highlight the very low decline in our assets, the ability. A lot of the value for CRC is concentrated on PDP.
We're never a capital-intensive business that needs to have a lot of rigs to maintain production and to generate cash flow. You can see that flow through our numbers, right? In a year where we don't have all the permits, we think we can deliver a plan for one and a half rigs this year, unless we get some a good outcome in the near term with the appeals process. It's a one and a half rig. It's not gonna be enough to hold production. You can see the cash flow generation of the business is extremely high. We're gonna take every dollar to buy back shares.
You know, going beyond 2023 right now, we don't know where this is gonna end up. I think we proved what we can do in 2022 with permits. We're gonna prove what we can do in 2023 with a more limited set of permits and doing a 1.5 rig program.
Maybe just phrasing this a different way. If you guys had unlimited permits in 2023, would you be laying the production decline?
If we had a permit , we would be doing what we did in 2022.
Okay. That's what I was sort of trying to get at. Okay. Just, you know, following up on the plan for this year, everything's in the Wilmington Field, it sounds like, focused on oil. Obviously, gas prices in California have been pretty volatile, but generally speaking, have been, you know, very robust. You know, why not try to drill some gas out there as well in California? You obviously have, I think, you know, some opportunities and some permits to do that, I believe.
Yeah. No, we saw in particular in January, very, very strong natural gas prices, around $47 per Mcf, that's flowing. As you know, we're a net long producer of natural gas. We produce about 30 Bcf more than we consume. We see those prices coming in very strong. The question with gas always, it's very seasonal, and it's more difficult to time. Definitely we're focused on natural gas and trying to bring more gas on board, and that's, you know, a part of the plan here is to develop that inventory.
I don't know, Jay, if you wanna add any other comments around what we see it in February and January and February. By the way, we are now doing first quarter guidance. We're doing quarterly guidance. You can see the anticipated realizations of natural gas that we're expecting in Q1 flow through those numbers.
Yeah. Kinda to speak to the realizations of what happened in December, we generally market most of our sales gas on a first-of-the-month index basis. During the month of December, for example, when prices ran out mid-month, we were not there to participate. Obviously, that approach served us pretty well when that first-of-the-month sales process served us well in January and again in February. To Francisco's point, roughly 90%-95% of the natural gas consumed in California comes in from out of state. We'd like to have a larger impact going forward, and that's part of our plan to figure out where can we have that positive impact.
Maybe Mac has one more thing to add.
Yeah, I mean, that's the benefit of being a long natural gas, you know, producer. We produce more than we consume. It was a nice result in January and February. Hey, Leo, I just wanted to go back and address something. You know, you had posed a question in the hypothetical about rig count. Unfortunately, we don't deal in hypotheticals. We deal in the circumstances that are in front of us. The circumstances that are in front of us is that we've laid out a drill plan that's based off of permits in hand and have reduced the uncertainty associated with any outcome associated with Kern County or any additional permits down the road.
Obviously, the question about gas is a good one because gas, you know, in the future has the possibility of being a transitionary fuel, if you will, or at least it's viewed as that way, and it's needed for the electrical grid out here. That's good to have that vision. The reality is, we're dealing with circumstances all the time, and what we look at in reality, non-hypothetical situation is how do we maximize cash flow generation and what do we do with that cash.
Thank you. We have a question now from Kalei Akamine from Bank of America. Kalei, please go ahead.
Hey, good morning, guys. Thanks for taking my questions. My first question is on cost. CRC is always screened at the higher end of unit cost in the peer group. Pre-COVID, my understanding is that you guys did as much as you possibly could, yet you're focusing your efforts here. I wanna understand what's different today, or maybe to ask it differently, under what premise are you guys cutting costs? You guys are declining this year between 5% and 7%. Are you now optimizing your permanent cost structure around a declining business?
Yeah, no, Kalei. Hey, how's it going? We, definitely we've taken a lot of cost over the last couple years, and we'll continue to be focused on cost. We did see, like everybody else, inflationary pressures, and those inflationary pressures that are driving costs in the business need to be offset so that we can maintain the margins. I think we're just committed to continue to evaluate cost. In a year like this year, where we're guiding to lower production, we need to align that cost structure to the production, right? That's what we're saying. It's obviously a focus on cost. It's just for the long-term viability of the business, something that we always do.
What is sustaining CapEx at the moment?
Say it again. What was that? Repeat, if you don't mind.
What is sustaining CapEx, the capital needed to hold the business, hold production flat?
Yeah, well, we said to hold the different moving parts. There's OpEx and CapEx that ultimately helps us keep production flat. When what we said is about $300 million keeps production flat, entry to exit. This program is, like we said, more of a 155 run rate, and that's what we're seeing. We're guiding to a 5%-7% decline.
Got it. My second question is on the Huntington Beach monetization. Pre-bankruptcy, the thought was that this land was worth about $1 billion, less remediation costs. What do you think that net value is today? What is the pathway to readying that asset for sale and ultimately executing on the sale?
Yeah. There's a lot in that question, and I think what we've answered in the past is, we're focused on the smaller property and because there's a lot of things to work through as you sell assets. We have a fantastic real estate portfolio or assets that can be turned into real estate, or in Elk Hills, for example, it's the Net Zero Industrial Park. We can do a lot with our fields. The Huntington Beach field is the largest, probably most attractive piece of that portfolio from a future development. What we're doing there is we're starting abandonment.
We started the entitlement process, which is needed to change the surface use to the most appropriate and best use going forward. We're still producing oil. It's a very, very valuable, you know, very profitable field. We're taking the steps. We're trying to assess where to go. Right now we're focused on monetizing the smaller property that ultimately helps inform the plans for the bigger piece of land.
Do you think it's gonna be difficult to get the rights to change the use of that land from oil and gas production to commercial development or real estate?
We don't know. I mean, it happens a lot in California. You can look, Kalei. There's a number of big developments, land that's been used for some for oil, some for other purposes. You can see, the... You know, these projects get done, but it's, you know, the timeline is variable and that's the work that we were starting to do.
Perfect. That's my two, so I will leave it there. Mac, Francisco, congratulations to both of you guys.
Great. Thank you.
Thanks, Kalei. Thank you.
Our next question comes from Eric Seeve from GoldenTree. Eric, please go ahead.
Hey, guys. Congratulations, to both of you, on the announcement and the title changes. My first question is, with respect to the production guidance, can you give us a sense of where, you know, not just 2023 average production, but, you know, beyond Q1 where you've already given guidance, can you give us a sense of the production cadence we should expect for Q2, Q3, and Q4 or an exit rate level?
Yeah, no. Hey, Eric. We are expecting, as we said, a very moderate decline as we go through the year. We, you know, we went through, you know, started the year, exited the year last year at three rigs and obviously that carries into this year. Now we're reducing the activity to now one full-time rig in Wilmington. That step down in activity will, I should tell you that over the next few quarters, will be declining and we think we can add OpEx dollars.
I mean, that ultimately the most efficient dollar that we can put to work is around downhole maintenance because that means it's an existing well board that we just need to bring back online, followed by capital workovers, which we take a different zone using the same well board, and then third is a new brand new well. By backing on the activity for new drilling, that's the capital needed to be able to fully offset the decline, and that's, we're right now looking to more of a 5%-7% decline year-over-year.
Okay. You've given guidance for, you know, Q1, the midpoint of guidance is around 90,000 BOE a day. I guess for the full year, the midpoint is around 88. That would sort of suggest that, hey, we could see production just stepping down sort of gradually, you know, maybe around 1,000 BOE per day per quarter. Obviously I appreciate that you don't know for sure and there will be unexpected twists and turns, but is that a fair way for investors to sort of think about the progression here?
Yeah. I mean, you quoted your numbers. We have obviously ranges. There may be some differences there, but in terms of the way to think about it, that's right. We have production coming in from last year that benefits Q1. You would expect a very gradual decline after that.
Okay, great. Thank you. Just wanna make sure I understand. You talk about a 1.5 rig program throughout the year. Does that mean 3 rigs in Q1 and then stepping down just to 1 rig for quarters two, three and four?
We exited with three rigs in 2022, which means we entered in Q1 of this year in three rigs. Now we stepped down to just one rig at Wilmington. That's it.
Okay, great. Thank you. I understand, you know, obviously the permitting issues in San Joaquin Basin now, but in the L.A. Basin, why only one rig there? It seems like given some of the dynamics, you know, around permitting there, it would seem like an ideal time to be more active. Why only run 1 rig there?
Yes. As we looked at, you know, in a year like this year, we really wanted to maximize cash flow. You know, it's the ability of this asset to, we've done this before. Sometimes you press forward and you accelerate activity, and sometimes you back away. This year we felt the best dollars were in OpEx and downhole maintenance and capital workovers, because obviously we're ranking the portfolio on a returns basis. We think that's the best use for every dollar.
It doesn't mean that another rig at Wilmington would not be attractive. It's just relative to where we thought we wanted to be for the year and what are the returns that we're getting for putting dollars in OpEx and capital workovers.
Hey, Eric, it's Mac. I just wanna echo what Francisco said, I think that the key to this year with the 1.5 rigs is to reduce uncertainty. This is a plan based off of permits in hand. As we go forward, you know, if the circumstances change, we'll consider those. Right now, after, you know, going through last year, several different rig lines and counts of rig lines, we wanted to put forth a plan that stabilize and then maximize the cash flow, as Francisco said, for the year.
Thank you. We have a follow-up question from Leo Mariani from Roth MKM. Leo, please go ahead.
Yeah. Hey, guys. Just wanted to follow up very quickly on the separation of the two businesses. You clearly talked about, you know, laying some groundwork here, and I understand there's preliminary steps involved here, but, you know, it sounds to me like you guys are pretty much intent on eventually, you know, getting these businesses, you know, separately. Do you envision potentially the carbon management business being a separate public company, you know, sort of down the road? Just trying to get a little bit more color around what the vision might be on the separate businesses here.
A great question. I don't know if I will answer it very clearly because we were working on a lot, and we are focused on maximizing the value of the company. I would tell you, Leo, that if I look at the reserves of the company, and if you look at the PDP value of the company, and then I look at what we think is the value of carbon management, we don't think it's there reflected in the stock price. We're gonna take the steps to unlock that. In what form and what the timeline is, we still need to work through that to make sure we have the optimal outcome here.
Okay. I appreciate that. Then just on hedging, just given, you know, sort of the, at least for now, kind of a less focus on less capital, would you guys anticipate, you know, doing less hedging, with less forward CapEx? How are you thinking about that?
You know, we talked about in the past, a lot of the hedges that we had in place, were put there when we went to bankruptcy, and those hedges are starting to roll off. We're seeing the benefit in particular in 2024, where we don't have a lot of that impact of the bankruptcy hedges. We think there's an amount of hedging that's needed in this business to be able to guarantee the returns as we invest on a go-forward basis.
We'll continue to assess where we are. We'll see how the year progresses and how the markets behave in terms of oil. At this point we feel 2023 is adequately hedged and, we'll see what, as the year progresses, what we think of 2024.
Okay, thanks.
This concludes our question and answer session. I would like to turn the conference back over to Francisco Leon for any closing remarks. Please, Francisco, go ahead.
Great. Thanks everybody for listening in. I look forward to seeing a lot of our shareholders next week at the various conferences and thanks for tuning in.
The conference has now concluded. Thank you for attending today's presentation. You may now disconnect.