Amplify Energy Corp (AMPY) 2023 Q4 法說會逐字稿

Welcome to Amplify Energy's fourth quarter 2023 investor conference call. Amplify's operating and financial results were released yesterday after market close on March 6, 2024, and are available on Amplify's website at www.amplifyenergy.com.

During this conference call, all participants will be in a listen only mode. Today's call is being recorded. A replay of the call will be accessible until March 21, 2024 by 800-654-1563 and then entering access code 28240256. I would now like to turn the conference over to Jim Frew, Senior Vice President, and Chief Financial Officer of Amplify Energy Corp.

Good morning, and welcome to the Amplify Energy conference call to discuss operating and financial results for the fourth quarter of 2023. Before we get started, we would like to remind you that some of our remarks may contain forward looking statements which reflect management's current views of future events and are subject to various risks, uncertainties, expectations, and assumptions.

Although management believes that the expectations reflected in such forward-looking statements are reasonable. It can give no assurances that such expectations will prove to be correct and undertakes no obligation and does not intend to update these forward-looking statements to reflect events or circumstances occurring after this earnings call.

Please refer to our press release and SEC filings for a list of factors that may cause actual results to differ materially from those in the forward-looking statements made during this call. In addition, the unaudited financial information that will be highlighted here is derived from our internal financial books, records, and reports. For additional detailed disclosure, we encourage you to read our Form 10-K, which was filed yesterday afternoon.

Also non-GAAP financial measures may be disclosed during this call. Reconciliations of those measures to comparable GAAP measures may be found in our earnings release or on our website at www.amplifyenergy.com.

During the call Martyn Willsher, Amplify's President, and Chief Executive Officer, will review our fourth quarter performance and provide an update regarding our previously announced strategic initiatives. Next, Dan Furbee, Senior Vice President, and Chief Operating Officer, will provide an overview of fourth quarter operational performance.

Following that, I will discuss fourth quarter financial results, provide an update on our balance sheet and liquidity, and provide additional details on our hedge book. Finally, Martyn will conclude our prepared remarks with comments regarding Amplify's 2024 guidance and provide final thoughts before opening the call up for questions.

With that, I will hand it over to Martyn.

Thank you, Jim. Amplify had a strong fourth quarter of 2023, capping up a successful and important year for the company. With respect to the fourth quarter, the company generated $25.2 million of adjusted EBITDA and $14.4 million of free cash flow. Fourth quarter production averaged 20,800 BOE per day a 1% increase from the prior quarter, while LOE came in 7% lower than the prior quarter on a per-BOE basis.

For the year, Amplify generated $88 million of adjusted EBITDA and $38 million of free cash flow, which was in line with company of 2023 guidance. Despite steep declines in natural gas and NGL prices throughout the year. In 2023 the company also materially improved its balance sheet, reducing net debt by approximately $95 million and establishing a new credit facility in the third quarter.

Operationally, the company achieved average net production of 20,500 BOE per day for the year, successfully returned beta to production and formed a Magnifying Energy Services to provide a variety of oilfield services to Amplify operated wells, reduce operating costs and provide greater operating control. I am extremely proud of the entire organization for the operational and financial progress we made in 2023, and they expect the company to continue the positive momentum this year.

With respect to the strategic initiatives, highlighted last quarter, the company engaged an investment bank to pursue the monetization of our oil-producing assets in Bairoil, Wyoming. As a reminder, we're exploring a complete divestiture of the asset as well as considering alternative structures with the goal of maximizing shareholder value. A successful Bairoil monetization will accelerate our ability to reduce debt outstanding and evaluate return of capital options. We will provide an update regarding this process on our next call.

At Beta following an in-depth technical review of the undeveloped potential in the field, we are pursuing a four well development program in 2024 for the first well, having been spud earlier this week. At current prices, the development program is forecast to generate attractive IRRs in excess of 100% and payback periods of less than one year. The first two wells are scheduled to be in production in the second quarter, and we will provide updates to the market when the results are available.

In summary, we continue to focus on optimizing cash flow generation while simultaneously pursuing our strategic initiative at Bairoil and Beta. We believe this plan will unlock additional value in Amplify's portfolio and deliver substantial benefits and long-term value to our shareholders.

With that, I will hand it over to Dan.

Thank you, Martyn. Total production for the fourth quarter averaged approximately 20,800 BOE per day, consisting of 41% oil, 18% NGLs and 41% natural gas. Full year 2023 production averaged 20,500 BOE per day, which was within our full year guidance. Production guidance of 19,000, 21,000 BOE per day for 2024 represents volumes, which are nearly flat year-over-year with a 12% increase in oil volumes for beta development offsetting natural decline of our gas-weighted assets.

This projection include approximately 15 days of scheduled shut-in Beta during the year to complete the electrification of the platforms, which will generate significant cost savings and reduce emissions in the future. The Beta development program is anticipated to bring on additional oil volumes in Q2 and Q4 of 2024. With the full impact of our initial development campaign realized 2025. Oil production growth will increase revenue realization in 2024 and improve the company's profitability going forward.

Additionally, we anticipate that our operating partners in the Eagle Ford will continue development in the second half of 2024, with completion adding incremental liquid weighted volume early 2025. Beta operating expenses for the full year 2023 were approximately $140 million or $18.66 per BOE, which was below the midpoint of our 2023 guidance range.

As a reminder, we brought the Beta field back to production in late April 2023. When normalizing for a full year of Beta operation 2023 Beta operating expenses would be approximately $147 million. Our team has been extremely focused on reducing operating costs throughout the asset base, and we began to realize the positive results from these efforts in the fourth quarter. We expect to continue improving our cost structure throughout 2024 and our guidance of midpoint of $143 million.

Our guidance range for Beta operating expenses does not include the impact of Magnify Energy Services, which is expected to ultimately generate between $2 million and $3 million of adjusted EBITDA that would have otherwise been captured by third-party service providers and LOE. Accounting for the effect of Magnify to our operating cost structure. We are projecting full year 2024 fee operating expenses totaled $140 million, which represents a $7 million savings compared to the normalized 2023 run rate, despite $7 million noncontrollable inflation related items such as higher interest rates and electric utility cost taking effect in this year.

A detailed reconciliation bridging last year's operating expenses to our expectations for 2024 can be found in our latest investor presentation currently available on our website. The cost savings realized in late 2023 and expected to continue in 2024 are the result of this significant reduction in Beta usage for ongoing electrification project at Beta. Optimizing chemical programs in our Oklahoma and East Texas fields, improving workover efficiencies and several other initiatives.

Magnify currently owns and operates compressors in East Texas, which eliminates significant third-party rental fee, performed nearly all of Amplify's could find work in East Texas and Oklahoma, utilizes on well test units, and provide other ancillary services for well remediation work. In 2024 Magnify intends to expand the scope and size of the services, it provides Amplify, including additional compression and water hauling services in filed, where we find to be advantageous to operate our own vacuum trucks.

Between the continued cost-saving projects being undertaken by Amplify and expanded services bought by Magnify, we endeavor to be the most efficient operator of mature low-decline, long-life asset. In 2023, we invest a total of $33.7 million in capital, which was near the low end of our guidance range. Approximately $90 million was invested Beta with $10 million spent on our electrification and emission reduction projects and $9 million spent on workovers and other capital projects necessary to bring Beta back production in April 2023.

We also invested $7 million in non-op Eagle Ford development in which [10] gross and 0.9 net wells were brought online the first half 2023 and have performed at or above expectations with average projected IRRs exceeding 50%. The remaining capital for 2023 of $8 million was on high-return well workovers and facility projects in our Oklahoma, East Texas and Bairoil assets.

For 2024, our capital investment is expected to be between $50 million to $60 million. As Martyn mentioned, we have initiated drilling program at Beta, but we anticipate drilling four wells in 2024 for a total capital investment of $20 million to $24 million. Also at Beta, we will finish the electrification project and other one-time facility upgrades, investing between $13 million and $15 million. The remaining of the interstate capital expenditures in 2021 is allocated non-operated, high-return, oil-weighted Eagle Ford drilling. Other capital workovers and facility projects across our operating asset base. And approximately $1 million invested in Magnify and the oilfield services business.

[Facility] project at Beta, which will be completed in the second half of 2024 involves the upgrade of our electric facilities through replacement of diesel driven injection pumps with electric pumps and the inflation of selective catalytic reducers on all natural gas and diesel-driven engine, which will almost completely eliminate our non-emissions.

Upon completion, we will see a further reduction in power costs by eliminating all Beta usage for production operations, which will be substituted with our produced natural gas and additional electricity purchased from the local utility onshore. We will also eliminate the purchase of non-emission credit, which is currently a significant operating costs. After creating these projects, we do not anticipate additional material facility investments of Beta in the near future, which will increase the free cash flow from Beta going forward.

In conjunction with the cost savings to be realized by the large facility projects that Beta, we also anticipate substantial production growth through our 2024 development program. We have spudded our first of four planned wells in 2024 and expect to brown line two wells in the second quarter and an additional two wells in the fourth quarter. The value proposition of further developing the Beta asset is very attractive. Beta is a world-class oilfield initially discovered and developed by Shell in the 98 drilling low-angle wells through massive, highly permeable [stacked sands].

The last significant drilling program, the asset consists of seven wells drilled by Amplify's credit [facility]. Three of these wells were drilled horizontally, targeting the [D sand] and delivered first year average production of approximately 350 gross barrels per day per well.

Our current development plan designed to sidetrack out of existing shut-in wells horizontally targeted the deeper, utilizing the latest rotary steerable and mapping while drilling technology. Ultimately place our wells in areas with highest remaining oil saturation. With an estimated well cost between $5 million and $6 million and minimal incremental operating costs associated with these additional wells, we anticipate IRR exceeding 100% and payback of less than one year.

The Beta field has assembled by a large growth asset for years to come as there are still significant resources remaining to be recovered. The original oil in place assets in the field range from 600 million to 1 billion barrels of oil, and with only approximately 100 million barrels recovered to date, the implied recovery factor is only between 11% to 16%. There are many analog be opened Southern California Basin with very similar reservoir properties that have recovered between 30% to 40% of the original oil in place. The analogous fields generally have much tighter well spacing compared to the Beta field, which presents us the opportunity for significant and build drilling.

With base development underway, the Beta facility projects scheduled to be completed this year. The expansion of Magnify Energy Services and the continued focus on cost-saving initiatives and identifying and executing high-return workover projects. We expect 2024 be a transformational year for the company, where we start to realize the full value of Amplify asset base.

With that, I will turn it over to Jim.

Thank you, Dan. I would now like to discuss full year 2023 and fourth quarter financial performance, balance sheet and liquidity and hedging.

With respect to fourth quarter financial performance, the company reported net income of approximately $43.6 million compared to a $13.4 million net loss in the prior quarter. The increase was primarily attributable to non-cash unrealized gains on commodity derivatives during the period. For 2023, Amplify generated $88 million of adjusted EBITDA. Despite falling gas prices, the company's adjusted EBITDA was near the midpoint of its guidance range. As Martyn previously mentioned, fourth quarter adjusted EBITDA was $25.2 million, up $5.7 million from the prior quarter. The quarter-over-quarter increase in adjusted EBITDA was primarily due to lower lease operating expenses and slightly higher oil production. Of note with beta coming back online in April, fourth quarter oil production increased to 41% of total production up from 31% in the first quarter of 2023.

With respect to lease operating costs for the full year 2023, Amplify's average LOE was $18.66 per BOE. This was slightly below the midpoint of 2023 guidance. In the fourth quarter, lease operating expenses averaged $18.14 per BOE, down 7% compared to the prior quarter. As Dan mentioned, we think there are several opportunities to continue reducing LOE and the company is actively pursuing those initiatives. For full year 2023 gathering, processing, and transportation costs averaged $2.78 per BOE, which was below the low end of the guidance range. Fourth quarter GPT costs were $2.66 per BOE. We expect these lower costs will continue into 2024.

Cash G&A in 2023 was $26.4 million or $3.53 per BOE, which was below the midpoint of guidance, in the fourth quarter of 2023. Cash G&A was $6.2 million or $3.25 per BOE, which was down $0.3 million from the prior quarter. Full year 2023 cash interest expense was $16.3 million. This was slightly above the high end of our guidance range. Despite aggressively paying down debt throughout the year. Rising interest rates created some headwinds.

In the fourth quarter, we incurred $3.8 million of interest expense, down $0.7 million compared to the prior quarter. As we continue to pay down debt, we expect interest expense will trend lower in 2024. Free cash flow, defined as adjusted EBITDA, less CapEx and cash interest expense was $38 million and $14.4 million for full year 2023, in fourth quarter 2023, respectively.

Both of these results were in line with expectations. Amplify has generated positive free cash flow in 14 of the last 15 quarters, illustrating the strong sustainable cash generating potential of our mature diversified asset base. As Dan mentioned, we are investing significant capital at Beta in the first half of 2024 and expect to realize the positive impacts to revenue and free cash flow in the second half of the year.

On October 19, 2023, we completed the regularly scheduled semi-annual redetermination of our borrowing base, which was reaffirmed at $150 million with elected commitments of $135 million. The next redetermination is expected to occur in the second quarter of 2024.

As of December 31, Amplify had net debt of approximately $94 million, consisting of $115 million outstanding under our revolving credit facility and $21 million of cash and cash equivalents. Net debt has been reduced approximately $95 million or 50% since December 31, 2022. At year end, the company's liquidity was $40 million in net debt to last 12-month adjusted EBITDA. It was 1.1 times.

As of March 6, our forecasted crude oil production was approximately 70% to 75% hedged for 2024, 45% to 50% hedged for 2025 and 10% to 50% hedged in 2026. On the gas side, we are 85% to 90% hedged for 2024 through 2025 and 45% to 50% hedged in 2026. The company will continue monitoring the market to opportunistically supplement its strong hedge positions going forward.

With that, I'll turn the call back to Martyn.

Thank you, Jim. On to guidance yesterday, we provided operational and financial guidance for 2024 with the current assumption that we retain Bairoil for the full year. If our monetization process is successful, we will update guidance as appropriate later in the year. As Dan previously mentioned, Amplify's 2024 capital budget is forecasted to be between $50 million and $60 million. On a development side, we expect to drill four operated wells at Beta and participate in [0.5 to 1] net non-operated wells in the Eagle Ford.

We also anticipate completing the electrification and emissions projects of Beta while funding facility and high-return workover projects for our entire portfolio. Due to the timing of the Beta development and facilities projects, we expect to invest 85% to 95% of our capital budget in the first three quarters of 2024. As a result of these investments, we anticipate that the fourth quarter 2024, the company will see a substantial increase in oil production and a lower cost structure of Beta, which will significantly increase our cash flow and the long-term value of the Beta assets.

Our average daily production forecast for the year ranges between 19,000 and 21,000 BOE per day with a commodity mix of approximately 42% oil, 16% NGLs, and 42% natural gas. Due to the development program Beta, we anticipate oil production as a percent of total production will increase throughout the year. For guidance purposes, we've assumed a WTI price of $75 per barrel and a Henry Hub natural gas price of $2.50 per MMBtu for 2024.

Based on these assumptions, we anticipate generating adjusted EBITDA of $90 million to $110 million and approximately $20 million to $40 million of free cash flow this year. Additional guidance details are provided in our earnings release and can be found in the latest investor presentation currently available on our website.

As we look ahead to the remainder of 2024, we are excited by the potential of our Beta development program and the impact of our successful monetization of our payroll assets. We believe these two critical initiatives, combined with our relentless focus on managing our cost structure, will provide a catalyst to market outperformance while also enhancing our flexibility as we consider our strategic path forward and evaluate potential capital return options.

With that, operator, we are now open for questions.

(Operator Instructions) Jeff Grampp, Alliance Global Partners.

Good morning guys thank you for the time.

Morning Jeff.

Was curious on starting first with Beta, so you guys are drilling the first well there now results coming in Q2. Do you have kind of a best guess for when those wells start flowing? Just to get a sense of kind of the contribution in Q2 and maybe into Q3, and I know IP rates aren't everything, but any kind of internal estimate or expectations you could share that kind of benchmark? Maybe what makes a good well there early on?

Yeah. Let me talk about timing and then give Dan the floor and the other part of your question. These usually will take a couple of months to kind of by the time you've drilled them, completed them, and started flowing them back. And so we may have some initial results by early May in our next call, but we're anticipating better results by kind of later in May and June and kind of that time frame. So we'll provide what we can by the next earnings call, but I think this is more likely a later in 2Q results and impact on the -- on our production base.

Yeah, Jeff, this is Dan. Initial production results, we said we're expecting our first year average production to be approximately 350 barrels of oil per day kind of based on the latest wells drilled here. And I'd say the profile of these wells is a much shallower decline than what you would see in the typical shale well-being conventional assets. So we're expecting IP rates obviously higher than 350 barrels of oil per day with a not an extremely steep decline. It's kind of the characteristics of this reservoir in the results.

Okay, great. That's really helpful. Thank you.

And sticking with Beta. So production's kind of above pre incident levels. I'm curious if you guys have any read or expectation on the sustainability of that. Is that maybe just a short term boost since it's been offline for a while or what you guys are kind of expecting on the PDP base wedge of production there?

Yeah. Since we brought Beta back on, we've been able to do some much more extensive cleanouts of the laterals and the wells and the screens in the wells. And we've been able to utilize the coiled tubing unit that was not previously available on our assets. So bringing in that unit, the uplift we've seen seems to be sustainable, and we've seen that uplift now on individual wells for going on six months, since we started our workover program since we brought the asset back on. So we're confident we're able to continue seeing these results on our workover and hopefully get increasing uplift from these projects.

Okay. Great. And maybe one more for me. On the LOE bridge slide that you guys have, and I appreciate the detail that went into that. On the cost inflation component specifically, I think you guys hit on a couple of items in the reports, but can you just kind of review specifically what you're seeing there on cost inflation? And then, curious, if you guys view that as kind of just a structural change to the cost profile going forward? Is that something Magnify could help with? Are there other things you guys could do to maybe mitigate that, any kind of commentary there with you again would be helpful.

Yeah. I think we highlighted two main items, which are an increase in regulated power costs which are basically just -- they got approved at a higher rate, in some cases, almost double digits, and those came kind of late in the year. And so we obviously push those into the forecast. And then our insurance costs really not related to Amplify any way. This isn't just an industry-wide, I think this is all company-wide increase in liability cost.

A lot of it's associated with automobile kind of incident costs, it's kind of impacting the entire market for liability claims and costs in the marketplace. I think this is something that a lot of companies will have to absorb. And we're obviously pointing it out specifically, but those are two of the things that kind of impacted us the most. Dan, do you want to go into that in any part of the question there?

Yeah. On the other parts of it, Magnify has done a really good job to offset some of these inflationary costs. If you go back to like 2022 with much higher gas prices, in East Texas, we saw a lot of inflation with things specifically around compression costs, and we have a lot of rental compression, bringing a lot of that compression in-house, we've been able to offset a lot of that. And we do expect compressor rates to come down over time as obviously it's going out with natural gas prices, there's just not as much activity in the East Texas region.

And then, yeah, like Martyn said, most of the cost inflation we are expecting this year are mainly the insurance rates and the regulated power costs, which we are currently looking for ways to reduce our power consumption across all of our assets. We think there's additional upside there to realize this year.

And this is obviously the bridge to 2024. A lot of the things we're doing this year will impact later in '24 and into '25, especially if we finish the electrification and the mission of projects. So we've already gotten some benefit from them, but there will be incremental benefits that will flow through later in the year and into 2025. And so this is kind of where we are now and obviously, but not where we intend to continue to progress from here.

Okay. Understood. Great. Appreciate the time, guys. Thank you.

Before we always try to survey our questions from our investors, one that we received that we did feel we wanted to kind of spend a little bit more time on is the timing of the Bairoil process from here. Bairoil a very technical asset. And so what we've started by doing is obviously reaching out to the most interested buyers, which is a pretty long list. And really working with them on the technical aspects of this deal.

Keep in mind, we are running this as a parallel process between both in asset, [outright] asset sale and a monetization for a different kind of securitization or other structure. So that's going to take a little bit longer than your traditional divestiture timing. We anticipate this will lead to some kind of results or decision somewhere between kind of the first quarter and second quarter earnings calls. So probably sometime in that kind of mid-summer time frame, June, July, somewhere in there. So we expect to have more information as of the May call, but likely the kind of completing somewhere in the months in between that call and the August call.

With that, I just wanted to say thank you to all of our employees for their outstanding efforts and dedication this year. I'd also like to express my appreciation to all of our stakeholders for their continuing support.

Thank you for participating on the call today. And as always, if there are any questions, please don't hesitate to reach out. Thank you, everyone.

This does conclude today's program. Thank you for your participation. You may disconnect at any time.