Good day, and welcome to the Talos Energy fourth quarter 2019 earnings conference call. All participants will be in a 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 your touch-tone phone. To withdraw your question, please press star then two. Please note that this event is being recorded. I would now like to turn the conference over to Sergio Maiworm. Please go ahead, sir.
Thank you, operator. Good morning, everyone, welcome to our fourth quarter of 2019 earnings conference call. Joining me here today to discuss our results are Tim Duncan, President and Chief Executive Officer, and Shane Young, Executive Vice President and Chief Financial Officer. Before we get started, I'd like to take this opportunity to remind you that our remarks today will include forward-looking statements. Actual results may differ materially from those contemplated by these forward-looking statements. Factors that could cause these results to differ materially are set forth in yesterday's press release and on Form 10-K for the year ended 2019, to be filed with the SEC later today. Any forward-looking statements that we make on this call are based on assumptions as of today, and we undertake no obligation to update these statements as a result of new information or future events.
During this call, we may present both GAAP and non-GAAP financial measures. A reconciliation of GAAP to non-GAAP measures was included in yesterday's earnings press release, which was filed with the SEC and which is also available on our website at talosenergy.com. Now I'd like to turn the call over to Tim.
Thank you, Sergio. I'm happy to present our fourth quarter 2019 results and discuss all that we accomplished throughout the year. Also on this call, we will address our response to the recent developments in the crude oil market. The fourth quarter brought another positive earnings quarter and significant free cash flow generation. More broadly, 2019 was a year of progress for Talos as we generated strong financial results, maintained a solid and competitive credit profile, and finalized the appraisal of our world-class Zama asset in offshore Mexico. We also announced and since closed a major acquisition of a portfolio of producing high cash flowing oil-weighted assets with additional scale and diversity to our business while preserving our conservative leverage and liquidity positions for the future. Recent events in the market and the resulting commodity price environment have introduced considerable uncertainty for many independent E&P companies.
Talos, however, is well-positioned to weather the current market conditions. Our portfolio of producing assets is resilient with premium pricing, to WTI, a favorable fiscal regime, and competitive lifting costs. Our balance sheet is well-positioned with a pro forma leverage of 1.2 x adjusted EBITDA, approximately $600 million in liquidity, and no near-term maturities. Finally, we've hedged approximately 10.6 million bbl of oil of 2020 production at approximately $54 a bbl WTI, which will help preserve our cash flow generation profile in the near term. In response to the recent trends in the market, we have decided to sharply and decisively reduce our 2020 capital program compared to our previous guidance. In total, we expect to reduce our 2020 spending by more than $125 million through a combination of lower capital investments and a reduction in our operating expenses.
The drilling projects that we expect to remain in our budget in 2020 are those focused on quick turnarounds to first oil and existing nearby infrastructure that can still come online in 2020 or early 2021, so we can maintain our already high levels of PDP asset coverage, which will further position us to withstand a prolonged downturn. With these measures, we estimate that we can sustain a positive free cash flow business at a break-even point below $30 a bbl with our hedges. We expect to provide additional detailed revised 2020 guidance in the coming week. Our management team has a deep industry experience and has seen commodity crises in the past, and we are prudently responding by cutting gross spending, addressing costs across the organization, and preserving our liquidity and credit profile.
Members of the management team were together and navigated the 2008, 2009 commodity crisis that resulted from the financial crisis, and we also successfully navigated the more recent 2015, 2016 crisis. Both times as a private company without access to the equity market. We have built our strategy of short-term contracts, low leverage, and active hedging to be able to successfully absorb these types of shocks in the market like the one we're going through right now. We are confident that Talos Energy is among the best-positioned independents to weather the current market environment. We want to put ourselves in a position to take advantage of opportunities that might present themselves on the other side of this downturn. With that backdrop, let's turn to our highlights for the quarter. Production for the quarter averaged 54,000 bbl equivalent per day, comprised of approximately 73% oil and 79% liquids.
We continue to receive premium pricing for WTI for our oil production with a realized price of $57.65 for the quarter, approximately $0.83 above the benchmark. This resulted in revenue for the quarter of $233 million. Adjusted EBITDA, inclusive of the impact of hedges, was approximately $156 million in the fourth quarter, with strong margins on a per barrel equivalent and a percentage basis of $31.37 per BOE and 67%, respectively. Capital expenditures inclusive of P&A spending totaled approximately $87 million for the quarter, resulting in free cash flow for the quarter of $44.4 million. On February 28th of 2020, we closed the acquisition we announced in December. In the fourth quarter of 2019, the acquired assets produced 18,700 bbl equivalent per day, and during the eight-month period between the effective date and closing, these assets generated approximately $100 million of free cash flow.
Therefore, the cash component of the purchase price was reduced accordingly from $385 million - $292 million. We funded this cash component primarily from our revolving credit facility and cash on hand. Concurrently with the closing of the acquisition, Talos' borrowing base was increased to $1.15 billion, which was secured prior to the announcement of the transaction in December and required the unanimous consent of the 16 banks in our bank syndicate. This acquisition is already bearing fruits beyond our original expectations. The Claiborne number three well has just reached total depth, and it was a success. The well logged 284 feet of true vertical pay across five different pay sands, surpassing pre-drill expectations.
Because the well encountered both more pay sands and more net pay than expected, the operator of the Claiborne Field, Beacon Offshore, will accelerate a recompletion on a different well in the field and then come back and complete the number three well with expected first oil by mid-2020. In offshore Mexico, earlier this year, we announced the results of Netherland, Sewell's independent evaluation of the Zama discovery. Netherland, Sewell's, quote, best estimate of the 2C gross recoverable resource estimate is to 670 MMbbl equivalent gross, with 60% of these volumes on Talos' Block 7. Talos continues to focus on front-end engineering design or FEED of the project. Our goal is to declare FID on this development still in 2020, so we can have first oil as soon as possible.
As we've mentioned before, the timing of FID is dependent on the conclusion of our unitization agreement with Pemex. We continue to be engaged with Pemex on those discussions, and we're hoping for a quick resolution. We remain excited about the potential of this project, not only for Talos and our partners, but also what they can represent for Mexico in the long term. We have over 1.7 million gross acres under lease and over 1 million of those on primary term acreage. The majority of this acreage doesn't expire until 2023 or beyond. Although we are making immediate cuts to maintain free cash flow generation during the current commodity environment, we still have a deep bench of opportunities that will be available for us to execute at the appropriate time.
As we look further into the coming months, we think several tenets of our approach to how we conservatively manage our balance sheet have positioned us to be successful in these uncertain times. We try to appropriately utilize our acquired infrastructure, which allows for better margins and more opportunity to generate free cash flow. We actively hedge to protect our cash flows from swings in commodity prices, and we maintain low leverage and avoid long-term rig contracts. I remain confident in the long-term outlook for Talos. I'll now turn it over to Shane to discuss details of our financial results.
Thank you, Tim. I will now provide further details on our financial performance during the fourth quarter of 2019 and our current focus on 2020, including select details on our revised capital guidance for the year, given the recent dislocations in the crude market. As previously mentioned, strong realized pricing, high oil weighting, and a lean cost structure resulted in another quarter of high-margin production with Adjusted EBITDA margins of $31.37 per BOE or 67%, with total Adjusted EBITDA for the quarter of approximately $156 million. After capital expenditures for the quarter of approximately $87 million and interest expense, free cash flow for the quarter was a strong $44 million. Adjusted net income for the quarter was $72 million, or $1.31 per diluted share. We are pleased to note that Talos generated positive adjusted net income and adjusted EPS for all four quarters in 2019.
Compared to our revised full year 2019 guidance, Talos concluded the year at the midpoint of our capital guidance at $545 million. In addition, we actually outperformed on total operating costs with a total of $245 million or $10 million below the low end of our guidance range. On the balance sheet, we concluded the year with approximately $739 million of net debt, inclusive of our HP-I financing lease, representing 1.2x net debt to LTM Adjusted EBITDA. Year-end debt included a $32 million deposit on our recent acquisition, which had not yet closed at year-end. On a pro forma basis for the closing of our acquisition on February 28th, we maintained the same 1.2 x net debt ratio. Also pro forma for the transaction, at closing, we had approximately $600 million of liquidity in cash or availability under our $1.15 billion RBL credit facility.
In response to recent developments in the crude markets, Talos is quickly making adjustments to protect our liquidity position, including significantly reducing our 2020 capital and operational spending plans. We expect to reduce our 2020 budget by more than $125 million, primarily from deferring certain capital projects. While these changes will have some impact on 2020 production, we do not expect them to be major, although they could delay production adds in future years. Moreover, we've asked the teams to reevaluate all operating and overhead expenses for any potential for additional efficiencies or savings. While we came into the year with a strong crude hedge book, we've continued to add the book in 2020, some at higher prices in January, others as recently as this week.
As you will see in our release last night, we currently have hedged 10.6 MMbbl at an average price above $54 per bbl WTI in 2020. We mentioned in our 2020 guidance in February that we expect to generate free cash flow down to the low $40s per barrel. The world has changed for the time being, and that's no longer satisfactory. We are responding accordingly. With these forthcoming changes, we will drive cash neutrality down to below $30 per bbl in 2020, and we will expect to remain free cash flow positive for the year in the current environment. We plan to provide greater detail on our revised guidance line items in the coming weeks. I would like to hand the call back over to Tim.
In summary, we're very aware of the challenges that the current commodity price scenario will present to the industry in the foreseeable future and the adjustments that we need to make. This awareness is born out of the experience of successfully managing other similar crises before, but also knowing that we have appropriately structured our business to navigate these situations. We're taking a prudent approach to our 2020 budget, as discussed earlier, and will continue to focus on maintaining the highest levels of liquidity to manage through this period. I truly believe that Talos will not only prevail in the current environment, but will thrive and be in a position to execute our deep bench of organic and business development opportunities when the market stabilizes. With that, I'll open the line for Q&A.
Thank you. We will now begin the question- and- answer session. To ask a question, you may press star then one on your touch-tone phone. If you are using a speakerphone, please pick up your handset before pressing the keys. If at any time your question has been addressed, and you would like to withdraw your question, please press star then two. At this time, we'll pause momentarily to assemble our roster. Our first question will come from Jeff Grampp of Northland Capital Markets. Please go ahead.
Morning, guys. Appreciate the thorough remarks there.
Hey, Jeff. How are you?
I'm okay. Was wondering, of the $125 million of savings that you guys cited you're looking to kind of finalize here in the next couple of months or whatnot, can you guys just talk about maybe from a high level, kind of the balancing act you guys are working to do in terms of maybe sacrificing, deferring some longer-term exploration upside versus lower risk kind of cash flowing projects in the near term and kind of maybe which of those two is getting the lion's share of the deferment, if you will?
Yeah, that's a good question. It's a couple things, Jeff. I would tell you mentioned cuts over the next couple of months. I mean, those are cuts that, to be sure, are immediate. When you've been through these before, and again, we've been through these before, I think you and I have talked about that. We've been lucky enough to never breach a bank covenant in 20 years and don't plan to. You have to react immediately. We pulled the team together over the weekend and had to focus on what are the most immediate things we can do. Then we asked this very question you asked, which is kind of what are we trying to manage and what are we trying to prioritize? We have a short rig contract, 120 days. That rig contract's focused on hooking up the Bullet Well.
It's focused on the waterflood project that we're doing in our Tornado field. We had great success in that first well out of the box on the ILX with Claiborne. What's nice about that. It's converting a recompletion. What you're trying to do with what you decide to keep in, yes, you might have to sacrifice some high impact exploration. Some of that, though, doesn't get canceled. Some of that, Jeff, just gets postponed. You have to have faith in the inventory you've created. Keep in mind, some of that inventory is by infrastructure. Some of that inventory might be bigger targets for later down the cycle of the portfolio life. You've got to believe you've built the business in a way that if you have to postpone some of the high-impact stuff, you can get back to that later.
I think that's why we wanted to reiterate our acreage position. Your strategy in the near term, that's one of the reasons I put it in the guidance announcement, and you can take a look at it, is we did a run at a lower price deck. When you do a reserve run at a lower price deck, you've got to kind of first mention the SEC deck, keep yourself legal, and then you can do a sensitivity at a lower price deck. You can see that in the earnings release. I think at $45 long-term, and again, that's long-term, that's not in the next couple of months. Always remember, we've got hedges in the next couple of months. You've got $2 billion approved developed value. You want to maintain that value. That's your collateralized value.
The focus of what we decide to keep is driven around, one, making sure we have a budget that can create free cash flow. Two, that those investments will stabilize and continue to prop up that proved developed value in a lower price deck. That's how we think about it. Again, the cuts got to be immediate. They may not be all of them. We'll go take a little more time with the team to dig into every layer. By the time we re-guide in a couple of weeks, there might be some more cuts. That's a little more of an itemized process. Over the weekend, you're getting out kind of more a butcher knife, and then over time, you get a little more of a scalpel.
You got to have faith in the business you created and how you created it, faith in your prospects long-term, which we've talked about, then you're managing that lower price deck reserve base and keeping that stabilized as you exit the year. That's how we think about it.
Got it. Appreciate that answer. For my follow-up, was wondering the potential of you guys kind of evaluating maybe any sell downs of any projects that maybe you really want to get after this year, but want to kind of be prudent on balancing and spending as you guys talked about. Is that something that you guys are contemplating in the year, or is that predicated at all or baked into that $125 million plus of savings that you guys referenced?
I think no. It's hard to bake in. I think you have to just look at the projects as you have them. Heaven knows what the market is kind of sell down on a prospect. I think you focus on the ones that you want to execute and what the interest on those are. Some of those have partners. Bullet has a partner. The Tornado project has a partner. You focus on those, and then you look at the other ones and say, "Hey, can we work with the partnership to maybe delay one to next year?" They're probably thinking the same thing. On some of the things you might want to do, you can package up and think about putting that into a program at a later date.
I think the idea that we're going to go ahead and re-guide something that has an assumption we can find a partner, probably isn't the smartest way to do it. I think you got to focus on what do you have, what can you control, what can you access, how can you go execute? Have you pulled enough cost out of the system, again, to generate material free cash flow in the current environment, but then also execute and convert some things to PDP, improved developed, by the end of the year, that becomes the base for a longer potential commodity cycle. Again, been through this before. We certainly can draw on those experiences. I think if you try to think, Hey, maybe I can find a sell-down partner, you're going to be swimming upstream. I don't think that's an assumption we'd want to make.
Got it. Understood. I appreciate the time. Thank you.
All right. Thanks, Jeff.
Again, if you have a question, please press star then one. Our next question will come from Richard Tullis of Capital One Securities. Please go ahead.
Hey, thanks. Good morning, Tim. It's nice to see a green ticker on the screen today, so that's an accomplishment there.
Well, Richard, if you jinxed it, I'm going to come right after you.
All right, I'll take responsibility. Tim, in this environment, what sort of rate of return hurdle rate do you typically look for future drilling projects using, say, a $40 oil price, maybe a $1.80 or $2 gas price?
No, that's fair. Look, what's interesting about that is, typically, we like to have them, the minimum low part is, say, 50%, 60% as we think about our portfolio. We might lower that a little bit because as you think about some of these things, when's the time to start thinking about lower cost of goods? Maybe you can accept a little lower rate of return at a lower deck knowing that, and you think about the life cycle of the project, and part of that project will probably see lower cost of goods, but you're not baking that in there. I would tell you what we're keeping in this plan still have the types of economics we would have no matter what. They're still greater than 50% IRRs, and part of that is for the reasons we've talked about in the past.
They're right there next to infrastructure, or the cost is sunk, and we're hooking up a well that we drilled last year. The things that we decided with the minimalist rig program we have to keep in are really focused on getting our infrastructure, using our infrastructure, getting PHA fees from third parties into our OPEX system, which is a reduction of our OPEX, adding things to our PDP set as we think about fall redeterminations, et cetera. That's the focus on that, and those typically have our highest IRRs. I think we've talked about in the past, when we construct our budget, no matter what the commodity environment is, and Richard, we've talked about this in the past. We have obligations we have to tend to with respect to P&A. We focus on asset management.
Those are the easiest things we can do to offset our decline, recompletions, workovers. We try to keep those in the system. We focus on our drilling program, and we think about our infrastructure stuff first, our high-impact stuff second. We love the high impact, but if you have to cancel something, you typically cancel that first. Hopefully, you can defer it, get back to that. That's where I answered the question with Jeff. Those sometimes have lower rate of returns because they have longer life cycles, and the PV discount, sometimes at a lower deck, particularly if it's flat, lowers the returns. Now, you know you're going to get lower cost of goods in those economic cycles.
Those are the ones you typically cancel first, hope you can go get those back, focus on your infrastructure, focus on your margins, keep the ship moving, and then be available when you get on the other side of that to be opportunistic.
That's helpful. Thank you, Tim. Then follow up. I found it interesting and helpful to have the table in the earnings release regarding the PV-10 at the much lower oil prices, the $45 and $2 gas. Roughly, what do you think the associated standardized measure may be at the same commodity prices?
Well, I think standardized measure in terms of just putting taxes into that?
Yes, P&A liability, all that.
Keep in mind, anytime we do this run, any P&A liability associated with proved reserves are in this. I'm glad you brought that up because I always want to make sure we emphasize that. We might have some near-term non-proved asset P&A liability. That could be $150 plus or minus $1 million in there. The question is, would these reserves and these flows have a tax liability to them to get them to the standardized measure? You could probably take off, what we take off 30%, 35%? I think the idea that you would have a kind of a tax liability in this environment would be pretty low. There might be some reductions to this, but I think there are one thing that the reason we did this, and by the way, you're uplifted by the market hedges.
There's things that would be in that uplift this value. There's things that could potentially bring down that value. I think some of those things offset. I think what's important, one of the reasons why we wanted to do the run for two reasons. One, I think it shows you a little bit of the asset coverage on proved developed against our current debt outstanding, and that there's plenty of asset coverage there. I think it also shows, look, you can take $1 billion off of this, $900 million off of this, wherever we are in the net debt, and Shane Young can elaborate, but it kind of shows where you still have equity value in these prices for the stock.
Obviously, look, everyone's trading away with some of the other broader market concerns, but we think there's a lot of equity value, obviously, even in a lower environment for the company. Anything else? All that makes sense, Richard?
It does. You're still green, thankfully.
Yeah. You're off the hook.
All right, guys. Thanks so much.
Again, if you have a question, please press star then one. Our next question will come from Marshall Carver of Heikkinen Energy Advisors. Please go ahead.
Yes. Thank you. I see the development well success at Claiborne. Do you have an expected rate on that when it comes online?
I don't yet, Marshall, and we'll think about it when we re-guide. The reason is what was nice about this project, and again, admittedly, we're not the operator, we're getting used to a couple of these projects and not being the operator, but the guys at Beacon Offshore Energy have done a great job, is because we actually had a little more success than we thought. We realized now we can go to another offset well and accelerate a recompletion. Instead of having one completion in play here, it looks like we have two completions in play. I think we got to study that. This is all kind of in the last several days, and so I think we need to study that and think about what's the impact of both of those completions. Either way, it's upside for us.
These are volumes that this is in their infrastructure system, so it's no different than if it was one of ours and by our infrastructure system. We think those wells can be online potentially by mid-year, at least certainly one of them in mid-year, and it'll have an impact in the fall when we do the redetermination. I don't have quite those numbers yet. Again, we're just kind of new to the partnership. We just closed the transaction. We'll think about what that looks like as we really tighten up this next round of guidance.
Okay. Thank you. With your reserve report just being published, what would you say the base decline is for the company? I guess pro forma with the new assets.
Yeah.
What do you think your base decline is?
I don't have it right out of the reserve report. I think one thing I've said in the past, and a little generic, but I think speaks generally with most of these offshore firms, is base decline, typically, we like to see it around 15%. How we get there is, there's three types of curves in a typical offshore well. The first, the front part of the curve, which can be flat or a very little bit of decline, good rock properties, you kind of hold it. Then the middle part of the curve, which is the exponential decline. That can be 20%, 25%, that middle part of a well curve. Then sometimes these things flatten out for whatever reason, water influx and it rolls over. It can be on compression. Whatever causes that late part to flat out.
Our view in a good offshore firm, you want to have a mix between those early wells, those flat parts, and then those, obviously, when you have mature wells, you're going to have that exponential piece. Putting that together, you get around 15%. In the absence of new completions, you can kind of expect that. That's one of the reasons why we want to keep some capital in the system to always have engaging those new wells, that flat part of the curve, so we're entering into a calendar year with the right combination. Getting to your question, 15% is typically the answer. The broader issue is really how do you have the right combination of wells year over year over year so you can kind of maintain the right types of decline that are manageable.
All right. Thank you.
Okay.
This concludes our question and answer session. I would like to turn the conference back over to Tim Duncan, President and Chief Executive Officer, for any closing remarks. Please go ahead, sir.
Thank you, operator. A couple closing remarks. One, it's certainly a difficult time. It's trying times. I think we wanted to provide some confidence that we've done this before, and we've looked at these difficult issues. We're going to attack them decisively, quickly. We're continuing to look to see if there's more to do. But we have a tremendous amount of faith in the long-term business model and what we've created and the inventory we have and how we can manage through this and still look forward to what it looks like a year from now, a year and a half from now. I also want to remind some folks on the call that we were planning on having an Analyst Day this afternoon. Hopefully, everyone got the notice that we're not having that Analyst Day for all the obvious reasons related to travel.
Just as a reminder, in case anyone didn't get that notice, that there won't be an Analyst Day this afternoon. We look forward to having that and peeling the onion back on all the things that we think make our business so interesting. Obviously right now, the focus is on hunkering down and getting through this oil price crisis. We will come back with some updated guidance. We hope to do that in the coming weeks. We're working hard tightening everything up that we talked about today. For the time being, I think that's where we landed with today's call. We appreciate everybody being on the call, and we look forward to speaking to so many of you soon.
The conference has now concluded. Thank you for attending today's presentation. You may now disconnect.