Montauk Renewables Q4 2023 Earnings Call Transcript

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March 14, 2024

There are 7 speakers on the call.

Operator

Good afternoon, everyone, and thank you for participating in today's conference call. I would like to turn the call over to Mr. John Ciroli as he provides some important cautions regarding forward looking statements and non GAAP financial measures contained in the earnings materials are made on this call. John, please go ahead.

Speaker 1

Thank you, and good afternoon, everyone. Welcome to Montauk Renewables' earnings conference call to review fiscal 2023 financial and operating results and developments. I'm John Sorrelli, Chief Legal Officer and Secretary at MonToc. Joining me today are Sean MacLean, Montauk's President and Chief Executive Officer, to discuss business development and Kevin Van Aslan, Chief Financial Officer, to discuss our 2023 financial and operating results. At this time, I would like to direct your attention to our forward looking disclosure statement.

Speaker 1

During this call, certain comments we make constitute forward looking statements and as such involve a number of assumptions, risks and uncertainties that could cause the company's actual results or performance to differ materially from those expressed in or implied by such forward looking statements. These risk factors and uncertainties are detailed in Montauk Renewables' SEC filings. Our remarks today may also include non GAAP financial measures. We present EBITDA and adjusted EBITDA metrics because we believe the measures assist investors in analyzing our performance across reporting periods on a consistent basis by excluding items that we do not believe are indicative of our core operating performance. These non GAAP financial measures are not prepared in accordance with generally accepted accounting principles.

Speaker 1

Additional details regarding these non GAAP financial measures, including reconciliations to the most directly comparable GAAP financial measures can be found in our slide presentation and in our fiscal 2023 earnings press release and Form 10 ks issued and filed this afternoon. Those are available also on our website at ir.montaukrenewables.com. After our prepared remarks, we will open the call to questions and we ask that you please keep the one question to accommodate as many as possible. And with that, I will turn the call over to Sean.

Speaker 2

Thank you, John. Good day, everyone, and thank you for joining our call. I will begin by summarizing our announced series of development projects we expect to materially contribute to Montauk's multifaceted growth strategy. In December 2023, we finalized a contract for the delivery of 140,000 tons per year of biogenic carbon dioxide from our 4 Texas RNG facilities to a North American subsidiary of European Energy. In satisfaction of this arrangement, we intend to capture, clean and liquefy CO2, which will then be transported to a new Texas based e methanol facility of European Energy.

Speaker 2

The delivery term is expected to last at least 15 years with deliveries expected in 2027. We expect our capital investment to approximate $15,000,000 per facility and anticipate that capital spend to begin during the second half of 2024 as we work to achieve our targeted 2027 commissioning. During 2023, we announced our planned entrance into South Carolina through the development of a new landfill gas to RNG facility, an opportunity won by Montauk through a competitive bidding process. The planned project is expected to contribute approximately 900 MMBTUs a day of production capacity upon commissioning. We are in the development phase of the project and have started to incur capital expenditures.

Speaker 2

While we continue to expect the utility interconnection specifically included in our development assumptions to accept our production from this facility, the utility will require certain distribution system upgrades. Though those upgrades do not directly impact our interconnection, they do extend our expectation of the completion of that interconnection and the commissioning of our new RNG facility into 2026. During 2023, we also announced our planned development of a landfill gas to RNG project in Irvine, California at the Frank R. Bowerman landfill. This new RNG facility is anticipated to process a large and growing volumes of biocas in excess of the existing capacity of our existing renewable electric generation facility on the Bowerman landfill, which we intend to both retain and operate alongside the new RNG facility.

Speaker 2

As previously disclosed, we continue to expect the capital investment to range between $85,000,000 95,000,000 dollars and anticipate the fully commissioned facility in 2026 to contribute approximately 3,600 MMBtus per day in production capacity, assuming currently forecasted biostock feedstock volumes that are projected to be available from the host landfill at the time of commissioning in 2026. I will now shift to an update on our various ongoing growth development projects starting with our digestion capacity expansion of our PECO Dairy Cluster project in Idaho. As previously disclosed, our dairy hosts began delivering the first two of 3 feedstock increases identified in our feedstock amendments, the catalyst for the expansion project. Also as previously disclosed, 3 of the 4 development payments were made to our dairy host related to those achieved feedstock increases. Our dairy hosts informed us that they expect to deliver the final increase in feedstock volumes in 2025, at which time we will make the final development payment.

Speaker 2

The California Air Resource Board approved after the public comment period ended in March 2023, our provisional carbon intensity score application with a CI score of negative 261.56. We released the remaining gas from storage in the Q2 of 2023 and recognized both RIN and LCFS credit revenues related to those storage releases during 2023. Regarding the physical commissioning of our Pico Dairy digestion capacity increase project, We successfully commissioned the first of 2 new digesters as well as our new reception pit, both of which became operational during the Q3 of 2023. We immediately began using the increased reception pit capacity and have been working to increase gas availability through the additional digestion capacity. We continue to commission the second and last of our new additional digesters, expect to complete commissioning during the Q2 of 2024 and increase gas availability into the Q3 of 2024.

Speaker 2

We continue to expect our digestion capacity expansion project will allow us to take advantage of the excess capacity in our existing RNG facility at this location. I will now discuss the many developments we have had related to our North Carolina swine waste energy development, Montauk Ag Renewables. We continue to work with our engineer of record through the optimization of improvements to our patented reactor technology. During the Q1 of 2023, we completed the relocation of our existing reactor from its original location in Magnolia, North Carolina to our new Turkey, North Carolina facility in an effort to centralize future feedstock processing. We executed a receipt interconnection agreement with Piedmont Natural Gas for our Perky, North Carolina location.

Speaker 2

Related to our interconnection, we signed a lease agreement with Piedmont Natural Gas to provide access to the Turkey, North Carolina property during the construction of the interconnection. In July 2023, we signed a Renewable Energy Certificate REC agreement with Duke Energy, Duke, under which Duke will purchase the swine waste recs from the conversion of swine waste feedstock into renewable energy. During the Q3 of 2023, our Board of Directors approved funding for the first phase of our development initiative in North Carolina. We continue to expect the 1st phase total capital investment to range between $140,000,000 160,000,000 which includes approximately $33,000,000 of cumulative expenditures through the end of 2023. We continue to expect the first of our 8 processing lines of this first phase to be operational in the Q2 of 2024 and we are currently planning for a rolling commissioning schedule for the remaining processing lines beginning the second half of twenty twenty four through the second half of 2025 with revenues beginning in 2025.

Speaker 2

Our Turkey, North Carolina project location was approved to participate in the Piedmont Natural Gas Renewable Pilot Program, which is a step towards obtaining the new renewable energy facility and REF designation under the North Carolina Utilities Commission, the NCUC. In January 2024, we received notification from the NCUC that our Turkey, North Carolina location was approved for both our NREF and a certificate of public convenience and necessity. This is a critical step towards obtaining the NREF designation and obtaining this designation could have an impact on the timing of utility infrastructure at our Turkey, North Carolina location. In March 2024, we submitted an amendment to our NREF designation to optimize its applicability to specific facilitatory componentry for which we expect a decision on that amendment during 2024. Upon completion of our first full phase of the Turkey, North Carolina project, we anticipate the ability to process feedstock from over 120,000 hog spaces per day, equating to over 200 tons of daily waste collection per day.

Speaker 2

We continue to expect to annually produce approximately 45,000 to 50,000 megawatt hour equivalents through the combination of 190,000 to 200,000 MMBTU and 25,000 to 30,000 Megawatt hours. Additionally, we continue to estimate the first phase of this project will produce 17,000 to 20,000 tons of organic fertilizer alternatives annually. During 2022, we announced our plans to construct a second RNG processing facility at the Apex landfill. This project is being driven by projections of biogas feedstock availability from the host landfill. As the landfill host continues to increase its waste intake, we believe that the additional 2,100 millimeters millimeters

Speaker 3

millimeters millimeters millimeters millimeters millimeters

Speaker 2

millimeters Btu per day of production capacity of our new facility will allow for us to process the landfill hosts currently forecasted increases in biogas feedstock volumes related to their projected increases in waste intake. While the landfill host continues to increase waste intake, we expect there could be a period where we have excess available capacity after the second facility is commissioned. We currently expect commercial operations during the Q4 of 2024. In 2024, we reached an agreement with 1 of our landfill hosts to sell back our gas rights in advance of their exploration impacting 1 of our smaller renewable electric generation operating facilities. The strategic decision to exit this facility was influenced by a mid-twenty 24 expiration of an above market power purchase agreement, the elimination of decommissioning asset removal or site restoration obligations, the sale proceeds of $1,000,000 being well in excess of the carrying value of this project and the offer to extend our gas rights at 2 of our existing RNG operating facilities Atascocita and Coastal Plains for an additional 5 years each.

Speaker 2

The effective date of this transaction will be October 1, 2024. And with that, I will turn the call over to Ken.

Speaker 3

Thank you, Sean. I will be discussing our 2023 financial and operating results. Please refer to our earnings press release and the supplemental slides that have been posted to our website for additional information. Total revenues in 2023 were $174,900,000 a decrease of $30,700,000 or 14.9 percent compared to $205,600,000 in 20.22. The primary driver for this decrease relates to a decrease a decrease of approximately 16.6% in realized RIN pricing during 2023 of $2.71 compared to $3.25 in 2022.

Speaker 3

Additionally contributing to the decrease was a decrease in natural gas index pricing of approximately 58.7% in 2023 of $2.74 compared to $6.64 in 2022. Total general and administrative expenses were $34,400,000 in 2023, an increase of $300,000 or 0.8 percent compared to $34,100,000 for 2022. Our general and administrative expenses for 2023 increased approximately $2,100,000 compared to 2022 associated with the 2022 Montauk Ag Renewable Stock Based Compensation Amendments to restricted share awards. Partially offsetting this increase was a reversal of approximately $1,000,000 in stock based compensation expense related to forfeited stock awards. Our professional fees expense was $4,600,000 in 2023, a decrease of $700,000 or 12.5 percent compared to $5,300,000 in 20 for 2023 increased approximately $400,000 compared to 2022, which is included in the aforementioned total 2023 increase of $2,100,000 for Montauk Ag Renewables.

Speaker 3

Finally, our rent expense was $700,000 in 2023, an increase of $300,000 or 69.6 percent compared to $400,000 in 2022. Turning to our segment operating metrics, I'll begin by reviewing our Renewable Natural Gas segment. We produced 5,500,000 MMBtu of RNG during 2023, flat compared to 5,500,000 MMBtu produced in 2022. Reduced preventative maintenance and well field optimization in 2023 at certain sites led to increased production, notably at our Pascacita facility producing 84,000 millimeters millimeters millimeters

Speaker 2

millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters

Speaker 3

Btu more in 2023 compared to 20 20 Offsetting these improvements were unrelated well field quality issues at other sites and portfolio wide weather anomalies, which lowered production led by our Rumpke facility producing 95,000 fewer MMBtu in 2023 compared to 20 22. Revenues 22. Revenues from the Renewable Natural Gas segment in 2022 were $156,400,000 a decrease of $39,800,000 or 20.3 percent compared to 196 $200,000 in 2022. Average commodity pricing for natural gas for 2023 was 58.7% lower than the prior year. During 2023, we self marketed R44,900,000 RINs, representing a R1,100,000 increase or 2.5% compared to R43,800,000 in 2022.

Speaker 3

The increase was primarily related to the prior period RIN volumes carried over into 2023 compared to 2022. Average realized pricing on RIN sales during 2023 was $2.71 as compared to $3.25 in 2022, a decrease of 16.6%. This compares to the average D3 RIN index price for 2023 of $2.63 being approximately 11.7 percent lower than the average D3 RIN index price in 2022 of $2.98 At December 31, 2023, we had approximately 400,000 MMBTUs available for RIN generation and had approximately 100,000 RINs generated and unsold. We had approximately 400,000 MMBTUs available for RIN generation and approximately 700,000 RINs generated and sold at December 31, 2022. Our operating and maintenance expenses for our RNG facilities in 2023 were $47,900,000 an increase of $4,200,000 or 9.5 percent compared to $43,700,000 in 20.22.

Speaker 3

Our RNG facilities reported reduced total segment utility expenses of approximately $2,100,000 in 2023 as compared to 2022. Other RNG operating and maintenance expenses increased approximately $6,300,000 in 2023 compared to 2022 as a result of facility preventative maintenance, repairs, well field operational enhancements and non capitalizable costs. The non capitalizable costs were reported at our PECO facility in connection with the digestion capacity increase project. Our profitability is highly dependent on the market price and environmental attributes, including the market price for RINs. As we self market a significant portion of our RINs, a decision not to commit to transfer available RINs during a period will impact our revenue and operating profit.

Speaker 3

We strategically determined not to transfer a significant amount of D3 RINs generated and available for transfer during the Q1 of 2024 based on our internal expectations related to the price of D3 RINs. As a result, we have approximately 2,900,000 RINs remaining in inventory for 2020 from 2023 gas production and have approximately R7,300,000 in inventory from 2024 gas production as of this call. The average price of these 3 RINs through the end of February was approximately 3 approximately 194,000 megawatt hours in renewable electricity during 2023, an increase of approximately 4,000 megawatt hours or 2.1% compared to 190,000 megawatt hours in 2022. Our security facility produced 5,000 megawatt hours more in 2023 compared to 2022 as a result of the prior period engine maintenance. Revenues from renewable electricity facilities in 2023 were $18,400,000 an increase of $1,200,000 or 7.4 percent compared to $17,200,000 in 2022.

Speaker 3

The increase is primarily driven by the timing of generation and monetization of REX and DPA pricing step ups at our Bowerman facility. Our renewable electricity generation, operating and maintenance expenses in 2023 were $11,700,000 a decrease of $1,300,000 or 10.2 percent compared to $13,100,000 in 2022. The decrease is primarily due to timing of scheduled preventative maintenance intervals at our Bowerman facility. During 2023, we recorded impairments of $900,000 a decrease of $4,000,000 or 81.4 percent compared to $4,900,000 in 2022. In 2023, we recorded impairments of approximately 800,000 dollars for specifically identified RNG machinery and feedstock processing equipment that were no longer in operational use as well as $100,000 in obsolete renewable electricity generation critical spares.

Speaker 3

As to the remaining long live asset groups, we concluded based on our annual cash flow assessment conducted for monitoring potential indicators of impairment in 2023 that the cash flows to be generated are significantly in excess of their carrying values of our operating sites due primarily to the length of the underlying gas rates agreement and we did not report any other impairments related to our cash flows assessments. This compares to a 2022 impairment of $2,100,000 for a renewable electric generation site, wherein the future forecast cash flows did not exceed the carrying value of the site's long lived assets and other 2022 specifically identified impairments totaling approximately 2,500,000 dollars Operating profit in 2023 was $23,600,000 a decrease of $21,000,000 or 47 percent compared to $44,600,000 in 2022. RNG operating profit for 2023 was $59,300,000 a decrease of $35,100,000 or 37.2 percent compared to $94,400,000 in 2022. Renewable electricity generation operating loss for 2023 was 600,000 dollars a decrease of $6,400,000 or 91.5 percent compared to $7,000,000 in 2022. Turning to the balance sheet, in December 2023, dollars 66,000,000 was outstanding under our term loan.

Speaker 3

As of December 31, 2023, the company's capacity available for borrowing under the revolving credit facility was 117,500,000 dollars During 2023, we generated $41,100,000 of cash from operating activities, a 49.4% decrease from the prior year ended December 31, 2022 of $81,800,000 In December 2023, we entered into the 4th amended and restated loan agreement and secured promissory note, the MNK amendment, I and between Montauk and Montauk Holdings Limited, amending and restating in its entirety the 3rd loan agreement and secured promissory note as amended. The balance of the loan remains unchanged at approximately $10,000,000 However, the amendment extends the maturity date to December 31, 2033. The terms of the amendment are otherwise substantially similar to the original loan agreement as previously disclosed, we entered into the MNK loan agreement in accordance with our obligations set forth in a transaction implementation agreement entered into by and among MNK and the other party thereto in connection with our 2021 initial public offering. Based on our estimate of the present value of our PICO earn out obligation, we reported an increase of approximately $1,300,000 to the earnout liability during 2023, an increase of $100,000 or 12.8 percent compared to $1,100,000 increase in 2022.

Speaker 3

This increase was recorded through our RNG segment royalty expense. For 2023, our capital expenditures were $63,100,000 of which $18,600,000 $13,700,000 and $13,100,000 were related to the ongoing development of Montauk Ag Renewables, the PECO facility digestion capacity increase and the 2nd Apex facility respectively. As of December 31, 2023, we had cash and cash equivalents of approximately 73,800,000 Adjusted EBITDA for 2023 was $46,500,000 a decrease of $24,000,000 or 34.0 percent compared to adjusted EBITDA of $70,500,000 for 2022. EBITDA for 2023 was $45,300,000 a decrease of $20,400,000 or 31.1 percent compared to EBITDA of $65,700,000 for 20.22. Net income for 2023 decreased $20,300,000 or 57.7 percent compared to net income for 2022.

Speaker 3

The decrease was primarily driven by price driven reductions to revenues of approximately $30,700,000 that were offset through our tiered royalty structure, which reduced our royalty expense in 2023 by approximately $9,300,000 leading to our $20,900,000 reduction in 2023 operating income. With that, I'll now turn the call back over to Sean.

Speaker 2

Thank you, Kevin. In closing, and though we don't provide guidance as to our internal expectations on the market price of environmental attributes, including the market price of D3 RINs, we would like to provide our full year 2024 outlook. For 2024, we expect our RNG production volumes to range between 5,800,000 6,100,000 MMBTUs with corresponding RNG revenues to range between $195,000,000 2 $15,000,000 We expect our 2024 renewable electricity production volumes to range between 190,000 200,000 megawatt hours with corresponding renewable electricity revenues to range between $18,000,000 $19,000,000 And with that, we will pause for any questions.

Operator

Thank Our first question comes from the line of Samya Jain with UBS. Your line is open.

Speaker 4

Hi, thank you for choosing my question. Also for Slide 8 in the deck, that was super helpful. I guess I was wondering, do you have a long term outlook regarding G2RIN pricing and LCFS pricing? Or how do you see a potential comp presidency impacting that?

Speaker 2

Excellent question. As we oftentimes say on these calls, there are opportunities to not give guidance or our views on what the forward prices are for environmental attributes, particularly E3 RINs. We do take note, however, of the 3 year guidance that has been provided by the EPA, representing 30% increases in the demand for those attributes. And we do acknowledge based on available data that is on the EPA's site for the renewable fuel standard, the relative monthly generation statistics, which do suggest a recurring shortage of the generation of those attributes related to the run rate that would be more indicative of the demand that you will have for those 3 year RVOs starting with 2024.

Operator

Thank you. Our next question comes from the line of Matthew Blair with Tudor, Pickering, Holt. Your line is open.

Speaker 5

Thank you and good afternoon. Hope you could talk a little bit more about the Q4 production. If I'm doing my math correctly, it looks like Q4 RNG production was actually down a little bit from Q3, which I remember was impacted by some weather issues. So did those weather issues reoccur in Q4? And what is your outlook for Q1?

Speaker 5

Would you expect things to bounce back? Thank you.

Speaker 3

Matthew, in regards to providing quarterly guidance, we continue to just provide annual guidance for which our guidance ranges are between 5 point $8,000,000 $6,100,000 millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters

Speaker 2

millimeters millimeters millimeters millimeters millimeters millimeters millimeters millimeters

Speaker 3

millimeters millimeters Btu. In regards to the Q4, weather contributed, but we also had some well host well field quality issues, primarily at our large site in Cincinnati, Ohio, which impacted our expectations as we closed out the Q4. In regards to ongoing weather anomalies, similar to Sean not wanting to predict the future of RIN prices, we try to manage our expectations through weather. But as of right now, our existing guidance range is up between $5,800,000 $6,100,000 MMBtu, are contemplating all of our expected contributions from our RNG portfolio across the year.

Operator

Thank you. Please standby for our next question. Our next question comes from the line of Craig Sheree with Tuohy Brothers. Your line is open.

Speaker 6

Hi, thanks for the updates and taking the question.

Speaker 3

Any thoughts

Speaker 6

as the North Carolina swine waste project is completed, your PECO expansion is brought online, you get your Apex expansion and then you also have the Blue Granite and Bowerman projects?

Speaker 3

Thanks, Craig. Yes, we do anticipate our EBITDA increase in 2024 to follow along with our increase of from our increase in expectations of volumes. RIN price notwithstanding based on our internal assumptions. In regards to the ramp in 2025, specifically related to our North Carolina operation, based on our current expectations, we look to fill around half of our expected output under the Duke Swine Rec agreement, with revenues starting around the second half of twenty twenty five. Thereafter, the EBITDA contributions from a more recent project that we announced, the European Energy, from a volumetric and price standpoint, I think it would be fair to say from a top line revenue contribution from European Energy, The pricing of that agreement is generally in line with some expected prices from a carbon sequestration tax credit view.

Speaker 3

However, I do want to note that this is not a tax credit play for us. It is a revenue driver increasing and diversifying our top line revenues whenever we start to deliver our volumetric CO2 to European Energy.

Operator

We have a follow-up question from the line of Matthew Blair with TPH. Your line is open.

Speaker 5

Hi, thanks for taking my follow-up. I was going to ask about your 2024 spending plans, but I'm actually seeing it in the K here. It looks like it's approximately $150,000,000 to 160 $7,000,000 Is that correct? And could you talk about what's driving the increase year over year?

Speaker 3

Yes, that is accurate, Matthew. Thank you. More poignantly, our annual maintenance capital disaggregated, we expect that to be between $14,000,000 $17,000,000 and then our development project capital ranges between $135,000,000 $150,000,000 That's largely driven by our 2 larger projects, the RNG build on the reactor lines at our North Carolina location.

Operator

Thank you. I'm showing no further questions in the queue. I would now like to turn the call back over to Sean for closing remarks.

Speaker 2

Thank you. And thank you for taking the time to join us on the conference call today. We look forward to speaking with you on our 2024 Q1 conference call.

Operator

Ladies and gentlemen, this concludes today's conference call. Thank you for your participation. You may now disconnect.

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Key Takeaways

  • Montauk signed a 15‐year offtake agreement with a subsidiary of European Energy to deliver 140,000 tons/year of biogenic CO₂ from its four Texas RNG facilities to a new e-methanol plant, targeting 2027 commissioning with ~\$15 million capex per site.
  • The company is developing three new landfill-to-RNG projects: a 900 MMBTU/day South Carolina plant (commissioning in 2026), a 3,600 MMBTU/day facility at Irvine, California (capex \$85–95 million, 2026), and a second 2,100 MMBTU/day Apex expansion expected online in Q4 2024.
  • Phase 1 of Montauk’s North Carolina swine waste RNG initiative is funded at \$140–160 million, with the first of eight processing lines operational in Q2 2024 and full phase commissioning rolling from H2 2024 through H2 2025, plus annual production of RNG and organic fertilizer.
  • In fiscal 2023, revenues declined 14.9% to \$174.9 million and Adjusted EBITDA fell 34% to \$46.5 million, primarily due to a 16.6% drop in RIN pricing and a 58.7% decrease in natural gas index prices, resulting in operating profit of \$23.6 million (down 47%).
  • For 2024, Montauk forecasts RNG production of 5.8–6.1 million MMBTU (revenues \$195–215 million) and renewable electricity generation of 190–200 thousand MWh (revenues \$18–19 million).
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Montauk Renewables Q4 2023
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