Ring Energy Inc (REI) 2021 Q4 法說會逐字稿

Good morning, and welcome to the Ring Energy Year-end 2021 Earnings Conference Call. (Operator Instructions). Please note this event is being recorded. I would now like to turn the conference over to Al Petrie, Investor Relations for Ring Energy. Please go ahead.

Thank you, Andrea, and good morning, everyone. We appreciate your interest in Ring Energy. We will begin our call with comments from Paul McKinney, our Chairman and CEO, who will provide an overview of key matters for the fourth quarter and full year. We will then turn the call over to Travis Thomas, Ring's Chief Financial Officer, who will review our financial results. Paul will then return to discuss our future plans and outlook before we open the call up for questions. Also joining us on the call today and available for the Q&A session are Alex Dyes, Executive VP of Engineering and Corporate Strategy; Marinos Baghdati, Executive VP of Operations; and Steve Brooks, Executive VP of Land, Legal, Human Resources and Marketing. During the Q&A session, we ask you to limit your questions to 1 and a followup. You are welcome to rejoin the queue later with additional questions. I would also note that we have posted a Q4 and full year 2021 investor presentation to our website. During the course of this conference call, the company will be making forward-looking statements within the meaning of federal securities laws. Investors are cautioned that forward-looking statements are not guarantees of future performance and those actual results or developments may differ materially from those projected in the forward-looking statements, and the company can give no assurance that such forward-looking statements will prove to be correct.

Ring Energy disclaims any intentions or obligations to update or revise any forward-looking statements whether as a result of new information, future events or otherwise. Accordingly, you should not place undue reliance on forward-looking statements. These and other risks are described in yesterday's press release and in our filings with the SEC. These documents can be found in the Investors section of our website. Should one or more of these risks materialize or should underlying assumptions prove incorrect, actual results may vary materially. This conference call also includes references to certain non-GAAP financial measures. Reconciliations of these non-GAAP financial measures to the most directly comparable measure under GAAP are contained in our earnings announcement released yesterday. Finally, as a reminder, this conference is being -- call is being recorded. I would now like to turn the call over to Paul McKinney, our Chairman and CEO.

Thank you, Al. Welcome, everybody, and thank you for your interest in Ring Energy and for joining us today for our fourth quarter and year-end 2021 earnings call. As you may know, we finished 2021 with strong fourth quarter results. We generated free cash flow of $9.3 million during the fourth quarter and $20.5 million of free cash flow during the full year 2021, marking our ninth consecutive quarter of producing positive cash flow. We use the cash flow to help pay down $23 million of debt in 2021, including $5 million during the fourth quarter, which helped us reduce our interest expense by almost 18% when compared to the prior year.

During the fourth quarter, we enjoyed higher product prices while continuing to make progress driving operational efficiencies that resulted in adjusted EBITDA and adjusted net income growth over the third quarter of 2021 of 21% and 46%, respectively. For the full year 2021, we posted adjusted EBITDA of $83.3 million and adjusted net income was $30.6 million, which was 48% higher than the full year 2020. We ended 2021 with $61.6 million of liquidity, a 10% increase from the end of the third quarter and 52% higher year-over-year. If you recall, we have a $1 billion revolving credit facility with a borrowing base of $350 million, which was reaffirmed in December.

Availability under our credit facility at December 31, 2021, was $59.2 million. With respect to our development initiatives, we continue to benefit from our successful 2021 drilling program that targeted high rate of return opportunities in our Northwest Shelf and Central Basin Platform areas. The result was, fourth quarter 2021 sequential sales volume growth of 11%, where we averaged 9,153 barrels of oil equivalent per day, of which 85% was oil. We concluded our 2021 drilling program with a Phase IV package of 2 wells that were drilled and completed on time and within budget and placed on production in the fourth quarter. Both wells have performed at or above expectations to date, which is consistent with the overall results of our 2021 program. We drilled 11 wells last year, including 8 wells in the Northwest Shelf and 3 wells in the Central Basin Platform. And we completed 13 wells, including 10 wells in the North West Shelf and 3 wells in the Central Basin Platform. My favorite part of what we accomplished last year in our drilling and completion program was our success in the Central Basin platform.

All 3 CBP wells are performing better than the average wells drilled there in the past, with 2 of our wells on course to exceed the ultimate recovery of the best wells drilled in the offsetting area. We accomplished this by focusing on the geology, selecting the best landing zones and improvements in our completion methods. We not only improved the performance of our wells, we unlocked incremental value from the legacy portion of our asset base.

In 2021, we also converted 25 wells from downhole electrical submersible pumps to rod pumps, something we call CTRs for short. In 2021, we converted 19 wells in the Northwest Shelf and 6 wells in the Central Basin Platform. The long-term benefit of our targeted CTR program comes in 2 forms. First, we were able to significantly reduce our operating costs through lower electricity usage and considerably lower repair costs.

The resulting lower operating costs drive the second benefit, which is the wells generally experienced longer economic lives leading to higher ultimate recovery of the oil and gas reserves. With respect to our reserves, our 2021 capital development program helped us grow our year-end 2021 SEC proved reserves by 2% to 77.8 million barrels of oil equivalent, more than replacing our production for the full year.

Turning to our 2022 outlook. On January 1, nearly 60% of our low price hedges rolled off, which allows us to capitalize on improved commodity prices and generate higher revenue and operating cash flow, assuming, of course, that commodity prices remain strong. In response, we are increasing our capital spending to organically grow production and adjusted EBITDA. We intend to continue paying down debt, and we plan to do so all within operating cash flow. The success of our 2021 program has given us confidence to increase our 2022 capital investment program, which is designed to enhance our scale and improve our financial metrics while dramatically reducing our leverage ratio.

We are forecasting a meaningful reduction of our leverage ratio from approximately 3.5x at December 31, 2021, to less than 2x at the end of 2022. As we have said earlier, we initiated our 1-rig continuous drilling program in late January, which is again focused on our highest rate of return inventory in both the Northwest Shelf and Central Basin Platform areas. To date, 4 wells have been drilled in the Central Basin Platform, including 2 wells that were placed on production earlier this month and 2 wells that are expected to be online in April.

By running a continuous drilling program, we believe we can more than offset the natural decline rates of our wells and grow our quarterly production levels starting in the second quarter. We anticipate full year production to increase almost 10% based on the midpoint of our guidance. Of course, we will continue to retain the ability to adjust our drilling and other capital spending programs to reflect material changes in our commodity prices. We currently plan to drill 25 to 33 wells in 2022 and complete 25 to 30 wells across our Northwest Shelf and Central Basin Platform acreage. The midpoint of our total capital spending guidance includes approximately 82% for drilling, completion and equipping activities. Completing our drilling program -- or I'm sorry, complementing our drilling program, we are allocating approximately 12% for continued execution of our successful CTR recompletion and capital workover programs with the remaining 6% intend for land-related costs and other miscellaneous spending.

Our guidance reflects our current view of the inflationary impact on our operating and development costs. Now before I turn this call over to Travis, I would like to share one more point with you concerning our ESG initiatives. Promoting environmental stewardship, supporting our employees and communities where we work and ensuring sound corporate governance are cornerstones of our culture. Last year, we made substantial progress on our ESG journey by issuing our inaugural ESG report, revising all of our charters and updating our corporate guidelines to be consistent with modern governance practices. We believe that ESG is not just the responsibility of our Board and our executive leadership, but also extend to our employees. Our inaugural report provides a great foundation upon which to build, and we will continue to demonstrate the importance of ESG to the long-term sustainability of this company.

So with that, I will turn it over to Travis to discuss our financial results in more detail. Travis?

Thanks, Paul, and good morning, everyone. For the fourth quarter of 2021, we generated revenues of $59.7 million and net income of $24.1 million or $0.20 per diluted share. Excluding the estimated after-tax impact of pretax items, including a $15.2 million noncash unrealized gain on hedges and approximately $900,000 for share-based compensation expense, our fourth quarter adjusted net income was $9.9 million or $0.10 per share. For the full year of 2021, we generated revenues of $196.3 million and net income of $3.3 million or $0.03 per diluted share.

Excluding the estimated after-tax impact of pretax items, including a $25.1 million noncash unrealized loss on hedges and $2.4 million for share-based compensation expense, our full year adjusted net income was $30.6 million or $0.31 per share. During the fourth quarter of 2021, we had approximately $20.6 million in cash flow from operations and $11.3 million in capital expenditures. The combined result was free cash flow of $9.3 million. For the full year 2021, we had approximately $69.5 million in cash flow from operations, $51 million in capital expenditures and $2 million in divestiture proceeds. The combined result was free cash flow of $20.5 million.

For the 3 months ended December 31, 2021, we had oil sales of 715,163 barrels and natural gas sales of 761,682 Mcf for a total of 842,110 Boe. Our fourth quarter of 2021 realized pricing was $76.35 per barrel of oil and $6.65 per Mcf natural gas for an average of $70.85 per Boe. The differential between our average oil price received at NYMEX WTI was a negative $1.12 per barrel for the fourth quarter of 2021 versus our third quarter average differential of a negative $1.05 per barrel.

Our average natural gas price differential from Henry Hub was a positive $1.85 per Mcf for the fourth quarter versus a third quarter positive differential of $1.43 per Mcf. For the full year of 2021, we had oil sales of 2,686,939 barrels. And natural gas sales of 2,535,188 Mcf for a total of 3,109,470 Boe. Our full year 2021 realized pricing was $67.56 per barrel of oil and $5.83 per Mcf for an average of $63.13 per Boe. For more details concerning our financials and other income statement line items, please refer to our earnings release and 10-K that was filed with the SEC yesterday. Of course, I will be happy to answer any questions you may have during today's Q&A sessions.

One of our top priorities coming into 2021 was to strengthen our balance sheet through debt reduction. Our strategy has been to capitalize on the organic opportunities within our portfolio to maintain production, increase liquidity and produce strong cash flows. We are pleased with our fourth quarter results as we once again generate free cash flow and strengthened our financial position by paying down debt, which in turn increased our liquidity. Looking forward, the levels of free cash flow and the cadence of debt paydown will continue to be driven by the timing of capital spending and market conditions. As of December 31, 2021, we had $290 million drawn on our revolving credit facility and liquidity of $61.6 million, including $2.4 million of cash and $59.2 million available on the revolver, which includes a reduction of approximately $800,000 for letters of credit. We are pleased to further pay down our revolver by $5 million in the fourth quarter, leading to a total debt reduction of $23 million for the full year of 2021.

Turning to our outlook for the first quarter and full year of 2022. As Paul discussed, for the full year 2022, we anticipate total capital spending of $120 million to $140 million, which includes estimated costs to drill 25 to 33 wells and complete 25 to 30 wells, primarily in the Northwest Shelf. Our full year capital spending outlook includes targeted well reactivations, workovers, infrastructure updates and continuing our successful CTR program in the Northwest Shelf and Central Basin Platform. Also included in the full year estimate is anticipated spending for leasing, contractual drilling obligations and nonoperated drilling, completion and capital workovers. We remain focused on further paying down debt and strengthening our financial position.

Our full year 2022 capital spending plans are expected to generate strong operating cash flows that fully fund our capital investment plans. Of course, as Paul noted, our 2022 capital spending program assumes a favorable commodity pricing environment. If prices were to pull back materially, we have the flexibility to reduce capital spending as necessary. Supported by our targeted capital development program and continued focus on maintaining operations excellence, we currently expect full year 2022 sales volumes of 9,000 to 9,600 Boe per day compared with full year 2021 average sales volumes of 8,519 Boe per day, a 9% year-over-year increase using the midpoint of our guidance.

Looking at the first quarter, drilling under our new continuous drilling program began in late January. As such, there is minimal additional production impact expected from the new wells in the first quarter. Including the expected normal decline in production during the first quarter and some short-term weather-related sales disruptions, first quarter 2022 sales are expected to be in the range of 8,500 to 8,700 Boe per day. Second quarter 2022 sales are expected to reflect the benefit of the new continuous drilling program. For full year of 2022, we anticipate LOE of $10.90 to $12 per Boe and gathering, processing and transportation, or GPT costs of $1.60 to $2 per Boe contributing to the increased LOE per Boe cost from 2021, our inflationary-related increases partially offset by lower anticipated operating costs from our targeted and ongoing CTR program and the purchase of previously leased ESPs.

Looking at operating costs for the first quarter, we currently expect LOE to range between $10.90 and $11.25 per Boe and GPT cost of $1.60 to $1.75 per Boe. Turning to our hedge position. As Paul discussed, we are pleased that the majority of our low-priced hedges rolled off January 1. This provides us with the opportunity for substantially higher revenue and operating cash flow in 2022 based on a continued strong oil price environment.

So with that, I will turn it back to Paul for his closing comments before Q&A. Paul?

Thank you, Travis. And as you just heard, we have a solid asset base that is generating strong operating cash flow and adjusted EBITDA, especially in the current pricing environment. We are planning to strategically and properly grow our production to build scale through a continuous drilling program. We believe that by increasing size and scale, we can more easily incorporate accretive acquisitions that meet our investment criteria and align with our strategic vision.

In closing, we speak to our shareholders regularly. And for some time now, they have expressed that once we got beyond 2021, they wanted to see us drill more in 2022. Like your management team and Board, they want us to build size and scale to reduce the volatility we have had in the past and become a more sustainable company. We believe our plans for increased drilling and capital investments this year puts us well on that path and does a small part to help the current supply situation the world is facing.

Nonetheless, we will monitor commodity prices to ensure our increased capital spending allows us to remain cash flow positive, reduce our debt and improve our leverage ratio. In summary, we are excited about the future. And Ring Energy is well positioned for continued success in 2022 and beyond.

And with that, I will turn this call over to Andrea for questions. Andrea?

(Operator Instructions) And our first question will come from Jeffrey Campbell of Alliance Global Partners.

Congratulations on staying the course on spending and debt reduction in 2021. I'll limit myself to 3 questions this morning. First, I wanted to ask if any third-party facilities downtime has been included in the 2022 guidance? And if so, is there any reasonable chance that this could improve over the course of the year?

Actually, it does. Things have improved as we've gone through 2022. There still is uncertainty associated with the third-party facilities. One of the big issues that we will face as we mark through our capital drilling program this year is the takeaway capacity for that gas production. As you know, we're drilling in both the Central Basin Platform and The Northwest Shelf. Both of those areas have their own and unique issues associated with gas takeaway and so it could be an issue. But our forecast right now have incorporated our best estimate and associated with that restriction.

Okay. Great. I appreciate that color. Second question, looking out into 2023, do you expect your bankers to continue to impose hedging requirements or maybe put another way, is there a debt level at which those requirements might be reduced or eliminated completely. And here, I'm kind of thinking of the 2x leverage goal that you've set for year-end 2022.

Yes, that's a good question. And our credit facility, the way it is currently written only requires us to maintain the hedges that we had in place from last year into 2022. There are no requirements going into 2023. And so the hedging activity that we will pursue will be one of what we've described in the past as an opportunistic hedging strategy. We believe it's the right thing to do to protect our cash flows and also put in the necessary protection so that we can pay down debt as planned.

But beyond those requirements, we believe our shareholders want to benefit from the marketplace or what they believe that the marketplace has to offer. And so we want our shareholders to participate in the marketplace. And so -- but we will have a responsible hedging strategy that does take advantage of the opportunities that the marketplace provides. Does that answer your question?

It does. And it's great to hear that you're going to ask complete freedom to do what you want to do in 2023.

Well, yes, complete freedom, I don't know about complete freedom, but yes, I'll go with you on that.

How about expanded freedom?

Expanded freedom, there you go.

Finally, your Delaware Basin update noted that the proceeds from the sale of (inaudible) consummated would go to further debt reduction. And I thought this was interesting, since in the past, there's usually been some mention of potential M&A as another variable. So I just wondered if you could expand on this a little bit.

There you go. The -- by taking the proceeds from the sale of our Delaware assets and applying that to that debt, that also increased our liquidity, it also increases our ability to take down another opportunity using cash. And so we are every bit as much focused on acquisitions and A&D as we have said in the past. There's volatility that you -- that we're all experiencing right now in the marketplace, has created kind of , I would just call it confusion, a lot of noise out there. So people don't know really what price deck to use. And so it's not that it's increased the gap between expected buyers and sellers, but it has created a lot of confusion because people are still questioning, okay, so what price deck do I want to use. As you saw -- just this morning, we saw another uptick in prices follow behind sharp reductions in oil prices as a result of the world's interpretation of what's going on over there between Russia and Ukraine. So -- but yes, we're still focused on acquisitions and divestitures, and we'll continue to be so. And our plan for the Delaware assets is once those are sold then we'll apply that to debt reduction.

Okay. Great. I appreciate the expansion. And again, congratulations on the fourth quarter, and we look forward to a good 2022.

The next question comes from Noel Parks of Tuohy Brothers.

Just a couple of things. The hedge you did layer in the 1,000 barrels a day at just shy of [85.] I was just curious how long had you been sort of monitoring the market in the strip before you decide to pull the trigger on that?

Well, we watch it pretty much every day. We get a report in every morning that kind of summarizes our [mark to market] differences in our hedge position in the current marketplace. And we look at the statistics. Like we've said in the past, we are pursuing and want to continue to pursue an opportunistic strategy that puts in the right defenses to protect our capital spending program and our debt repayment plans. But this last year, or earlier this year, I should say, when the opportunity came along, we were at -- we were looking at some historical records associated with what was out there in the marketplace. And we decided that with an additional contract of 1,000 barrels a day that went a long way to ensuring our capital spending and our debt repayment plans and so we took it.

Great. And with cost inflation being such a hot topic these days, I wonder if you could talk about the arrangement you have for your rig and whether you have it under contract or just paying a spot rate for it and just what your outlook is there?

Yes. We have a 5-well rolling contract with our drilling contractor right now. And that contract allows both parties to make adjustments as you roll along throughout the year to take into account inflationary measures. And so due to the volatility that we've experienced, we've seen spurts of really high rates of inflation, and then things level off and it's all associated with the supply chain, what's going on around the world. And I'll just take pipe, for example. If you look at our pipe prices today versus what we were pain in the fourth quarter of 2020, we're more than double those costs now. And so we've seen increases now across the board, whereas initially, they were still prices. But now we've seen price increases for all the goods and services that we use, whether it's cementing or fracking or just whatever it is. And so we'll see how things go. It is my prediction, though, that the supply chain will start to level out as we go throughout the year.

Oh, great. Anything in particular that steers you in that direction?

Well, I mean, the world has always been good to respond to change in situations. And so yes, we've seen some volatility. We've seen some pretty significant inflation in various different areas and the manufacturing process. Whenever prices get really, really high for any one product, somebody else decides they want to get into the business. And so you -- just the supply and demand situation has proven that our capitalist society has always been able to respond to the needs of the economy. And I'm confident that American people will follow through again.

(Operator Instructions) And our next question will come from Neal Dingmann of Truist.

All my questions -- you guys done a good job. You and Travis were laying out what you're seeing for this quarter, next quarter on production. I guess I don't want to get ahead of myself, but if prices at all start to come down, as you said, for some of the OFS, would you all even consider -- I mean I look at and say, I love the quick payback, the high returns you all have, would you all consider even adding more activity either through workovers or another rig if, again, overall macro prices remain high and service costs even go lower?

Yes. And you bring up a really interesting point, Neal. Right now, all the things we've addressed basically would suggest that we're going to be responsible with respect to our capital spending plan that we're going to stay within cash flow. So if you take your scenario you just laid out and cash flows actually increased even considerably more, yes, that's going to allow us to pay down debt faster, but it's also going to give us the opportunity to accelerate our capital spending programs. Now there are some realistic limitations to our capital spending program.

So let's talk about some of those. One of those I mentioned a little bit earlier, our gas takeaway in both the Central Basin Platform and the Northwest Shelf, although they are for different reasons, there are limitations to how much gas we can take away. And so if we get ahead of ourselves and drill really fast (inaudible) we pick up a second rig, we may outstrip the ability for gas takeaway. The other issue that we have, even though it's not as acute would be our water disposal. Right now, we have the water disposal facilities necessary for the wells we plan to drill. But it's going to be close too. And so the investment necessary to increase our disposal capacity is not that much, so we could probably take care of that. But the biggest limitation probably would be gas takeaway, and that would limit how much growth we could actually have, at least in the areas that we're currently focused.

No, it totally makes sense. And then what are you seeing Paul as far as the little -- you had either higher working interest or just again, I'm not talking particularly on big

deals, but you guys always seem to be sort of scoured. And I'm just wondering what the competition is like either for bolt-ons, either on the platform, the shelf? Are there opportunities? How does it look today versus, let's say, a year ago? And is that bid-ask spread pretty wide or not necessarily (inaudible) because of maybe less competition?

Yes, we have -- although we have participated in some of the marketed deals that other people have bid on and were successful, we participated. We have been unsuccessful in 1 or 2 of the attempts that we thought would be a great bolt-on to the company. But our preferred method is to go to the principles of that own and operate certain assets and try to negotiate something off the market. And that's because we're persnickety might be the right word. We don't want to dilute the various metrics that have led to our, what we consider, superior returns. So we have really low shallow declines.

We have high margins in our operated wells, the undeveloped opportunities have really superior economics. And so what we're trying to do is we're trying to be disciplined. We're trying to acquire assets that meet that criteria. Those are also the superior assets out there in the marketplace that everybody wants, right? So the competition is pretty stiff. And so the thing that has really kept us from really being successful up to now, I think, is really our balance sheet. We have tried to use a combination of cash and equity. But as you know, our strategy has been all along. We haven't been secretive about this at all. We have been willing to use equity and cash in a transaction, but the goal was always to take care of our existing shareholders by making sure it's accretive on the tail end of that transaction.

It would be accretive on whatever metric you want to use, whether it's cash flow per share, reserves per share, production per share. But at the same time, it will also be a leverage ratio reducing activity, strengthening the balance sheet, strengthening the credit facility. That's not been an easy thing to do. But we are very, very active. Every single day, we're working on those opportunities. We keep making phone calls. Others have called us. And so we're looking for partners that want to help us do that because anybody who takes our stock, of course, will be a partner, right? And so it is something that we work on every single day. Now getting back to your point about bid-ask and sell spreads. Yes, there's always that out there. These volatile times make it probably a little more challenging, but there are ways to overcome that. And so you can put in contingent payments associated with, okay, let's say, these oil prices stay high for a longer period of time than what the [forward] strip is showing. Well, then you put some kind of a contingent payment out there if oil prices are higher or you come up with other creative ways of bringing a deal down. And also reduce the anxiety associated with the difference between what the buyers and the sellers are trying to achieve.

No, that makes sense. And then just lastly, you touched on this a little bit, what you guys talked about a lot. I don't know if you are one of the guys who want to get operationally, but you guys continue to hit some of these record wells. Is it just sort of what you're continuing to learn? Is it through more efficiencies? I mean what's driving that? Again, I don't know if you guys have even given yourselves enough credit, but I'd love to hear more on what's pushing these results.

Yes. All the credit goes to my geoscience and engineering teams. These guys, they strive for excellence every day. We keep our ear to the ground, and we continue to walk in circles of others in the industry that are out there on the leading edge. We don't want to be on the bleeding edge, but by staying close to those communities, keeping close contact with those that are developing new technologies and learning what are those technologies would apply to our specific rock because every rock is different. And so -- but I give all the credit to our operating team and also our completions and drilling teams.

We're staying up on all the technologies. Our geoscience guys have really focused on the geology and petrophysics nailing the landing zones. And so if you look at what we did in the Central Basin Platform, yes, our teams -- our technical team just nailed it. And so I can't tell you how happy I am with respect to that. Because for a time period, we were concentrating our investments up there in the Northwest Shelf, but we had so much legacy acreage and so many undrilled opportunities in the Central Basin Platform, it's great now that we've been able to focus on the technology and now really unlock the value of that. And those economics, although they used to be considered inferior, I mean I'm not so sure if they're that inferior they're -- they've really, really strong economics. And so the difference between the breakeven costs of one area to the other is arguably within our margin of error to calculate and the variability between wells.

And so yes, we're talking about $25 breakeven cost in the Northwest Shelf, but Central Basin Platform is probably in the vicinity of $30 or so.

(Operator Instructions) Our next question will come from [Dennis Richter,] a Private Investor.

Paul, congratulations to a great 2001. So Paul, actually, you just answered one of my questions, and it was regarding the Central Basin Platform, your recent wells and how they compare to the Northwest Shelf. And can you give a little bit more color in terms of how much running room you have in terms of acreage that is -- or how many drilling locations you possibly could have there with those kind of economics?

Well, Dennis, I got to tell you, I don't have the number of undeveloped locations in our newly completed reserve report for those areas, but I do know that right now, our plans for 2022 include 9 wells in the Central Basin Platform, 4 of those have already been drilled. When looking at the economics, again, and the performance of the 3 wells that we drilled in 2021, they look really, really strong. Now although the rest right now is slated for the Northwest Shelf, our guidance range also allows for probably another 8 or so wells where we haven't completed the work. And so will we go back down to the Central Basin Platform, we do have more locations down there to drill. And of course, we also have a really handsome inventory of undrilled locations in Northwest Shelf still as well. And so -- but for this year, I know for sure, we've got -- unless energy prices fall below levels that we're currently anticipating, right now, we've got 9 wells slated for the Central Basin Platform and the remaining 16 or so in the Northwest Shelf.

Okay. And just one other question, and this is a little bit in terms of the CO2 kind of secondary recovery or a waterflood potential, something that this is your neighbor in the Northwest Shelf, Riley Exploration Permian, they are doing a pilot project. Just wanted to see if in terms of the potential there to do something like that, if that is being looked at. And if you can shed some color on that, if you -- they talk about being able to recover possibly 3 to 5x the primary recovery in that acreage and right -- you have your acreage right next to it.

So I just wanted to see if you willing to give some kind of perspective on that.

Yes. So Dennis, it's just to let you know. And we know the Riley Permian guys well. We've all traded secrets and shared our opinions, are aware of their programs. We've actually had a conference call with those guys where we talked about their operations, our operations, their plans for their CO2 program. As you may know, maybe you don't, but the section where they permitted their CO2 and water injection wells are in the section right next to our wells. And so yes, we shared quite a bit of information. We wish them all the best. This goes back to developing technologies. It takes -- you take on additional risk when you try these new ideas. But if the ideas -- pardon me, I'm losing my throat here. But if those ideas generate positive results, well, then that type of an opportunity will -- can be applied to all the (inaudible) horizontal oil play up there in the Yokum County area. And so not only would it benefit Riley Permian but it would also benefit the other operators that choose to apply that technology. And so we're all standing back. (inaudible) we really hope that they have really strong success because their success could also lead to success and additional recoveries for us.

This concludes our question-and-answer session. I would like to turn the conference back over to Paul McKinney for any closing remarks.

Thank you, Andrea. And all of you that have joined us on the call thank you very much. Thank you for the questions and the interest in Ring. We're looking forward to a really strong year this year. And just -- we hope that you'll continue to invest and trust your investment with us because we're working hard for you. This concludes our meeting for today.

The conference has now concluded. Thank you for attending today's presentation, and you may now disconnect.