10-Q: Montauk Renewables Reports Q2 Loss Amid Rising Costs

Montauk Renewables, Inc. reported a net loss for the second quarter and first half of 2025, driven by increased operating expenses and lower realized RIN prices, despite revenue growth.

Summary

• Total operating revenues for the six months ended June 30, 2025, increased by 6.8% to $87,730 thousand, up from $82,125 thousand in the same period of 2024.
• The company reported a net loss of $5,951 thousand for the first six months of 2025, a significant decline from a net income of $1,138 thousand in the prior year period.
• Operating expenses surged by 13.7% to $89,676 thousand for the first six months of 2025, compared to $78,889 thousand in 2024.
• Adjusted EBITDA for the six months ended June 30, 2025, decreased to $13,820 thousand from $16,434 thousand in the comparable 2024 period.
• RNG production volumes saw a slight increase of 0.3% to 2,802 MMBtu for the first six months of 2025.
• Realized RIN prices decreased by 23.9% to an average of $2.42 for the first six months of 2025, down from $3.18 in 2024.
• The Second Apex RNG Facility was completed and commissioned in June 2025, adding 2,100 MMBtu/day of production capacity.
• Capital expenditures for the first six months of 2025 totaled $45,298 thousand, with significant investments in Montauk Ag Renewables ($27,663 thousand), Rumpke RNG relocation ($8,409 thousand), and Second Apex RNG facility ($7,289 thousand).
• The company recorded an impairment loss of $2,424 thousand for the first six months of 2025, primarily due to a development project RNG interconnection no longer being accepted by the local utility.
• Cash and cash equivalents decreased to $29,133 thousand as of June 30, 2025, from $45,621 thousand at December 31, 2024.

Sentiment

Score: 3

Explanation: The sentiment is negative due to a significant shift from net income to net loss, a decline in operating income and Adjusted EBITDA, and a substantial impairment loss. While revenue grew and new projects were commissioned, these positives are overshadowed by rising operating costs, lower realized RIN prices, and project delays. The increased debt and ongoing operational challenges at existing sites add to the negative outlook, despite long-term growth plans.

Positives

• Total operating revenues increased by 6.8% for the six months ended June 30, 2025, demonstrating continued top-line growth.
• RNG production volumes showed a slight increase, indicating stable core production capabilities.
• The Second Apex RNG Facility was successfully completed and commissioned in June 2025, adding 2,100 MMBtu/day of new production capacity.
• The company signed a 15-year contract in 2024 for the delivery of 140 tons per year of biogenic carbon dioxide (CO2) to European Energy, with estimated total revenues ranging from $170,000 to $201,000 over the term.
• The collaboration with Emvolon for waste-stream biogas recovery has shown promising results in its initial pilot project, with plans for significant future deployment.
• The GreenWave Joint Venture was formed to expand RNG utilization for transportation, with Montauk Renewables acting as the RIN separator and expecting distributions.
• The Tax Reconciliation Act, signed July 4, 2025, extends the Section 45 Production Tax Credit and includes 100% bonus depreciation for qualifying assets, potentially offering significant tax benefits.
• The company recorded $826 thousand in Section 48 investment tax credits for its 2024 Pico digestion expansion project, with further significant tax credit potential from new projects like Second Apex RNG ($1,050-$2,100 thousand) and Montauk Ag Renewables ($4,500-$9,000 thousand).

Negatives

• The company reported a net loss of $5,951 thousand for the first six months of 2025, a substantial reversal from net income in the prior year.
• Operating expenses increased significantly by 13.7% for the first six months of 2025, outpacing revenue growth.
• Operating income shifted to a loss of $1,946 thousand for the first six months of 2025, compared to an income of $3,236 thousand in 2024.
• Adjusted EBITDA decreased by 15.9% for the first six months of 2025, indicating reduced operational profitability.
• Average realized RIN prices decreased by 23.9% to $2.42 for the first six months of 2025, negatively impacting revenue from Environmental Attributes.
• Renewable Electricity Generation volumes decreased by 11.1% for the first six months of 2025.
• A significant impairment loss of $2,424 thousand was recorded due to a utility no longer accepting RNG into its distribution system for the Blue Granite RNG Project, leading to a pause in capital expenditures for this site.
• Approximately 3,009 RINs were generated but unseparated at June 30, 2025, due to EPA BRRR K2 separation and compliance period extension, impacting RINs available for sale.
• Employee termination in Q2 2025 led to a one-time non-cash stock compensation expense of $1,550 thousand.
• The company's debt increased to $70,000 thousand as of June 30, 2025, from $56,000 thousand at December 31, 2024.

Risks

• Reduction or elimination of government economic incentives to the renewable energy market could adversely affect profitability.
• Inability to complete strategic development opportunities, such as the Blue Granite RNG Project, due to external factors like utility non-acceptance.
• Widespread manmade, natural, or other disasters, health emergencies, or geopolitical instabilities could impact general economic conditions and business results.
• Continued inflation or rising interest rates could increase operating costs or construction costs of projects and borrowing costs.
• Dependence on third parties for manufacturing products and services and landfill operations poses supply chain and operational risks.
• Quantity, quality, and consistency of feedstock volumes from landfill and livestock farm operations can fluctuate, impacting production.
• Reliance on interconnections with and access to electric utility distribution and transmission facilities and gas transportation pipelines.
• Projects may not produce expected levels of output due to operational issues or external factors.
• Concentration of revenues from a small number of customers and projects creates customer-specific risk.
• Outstanding indebtedness and restrictions under the credit facility could limit financial flexibility.
• Ability to extend fuel supply agreements prior to expiration at favorable terms is uncertain.
• Existing regulations and changes to regulations and policies, such as the EPA's RFS program and CARB's LCFS rules, can significantly impact operations and profitability.
• Market volatility and fluctuations in commodity prices and Environmental Attribute prices (RINs, LCFS credits) pose significant financial risk.
• Potential liabilities from contamination and environmental conditions, and exposure to extensive environmental, health, and safety laws.
• Impacts of climate change, extreme weather patterns, and natural disasters on operations.
• Failure of information technology and data security systems.
• Increased competition in markets.
• Continuing to keep up with technology innovations.
• Concentrated stock ownership by a few stockholders could influence voting outcomes.
• Landfill hosts delaying installation of wellfield collection infrastructure, impacting feedstock gas projections and production increases.
• Wellfield extraction environmental factors continue to impact gas extraction at Rumpke and Apex facilities, requiring ongoing mitigation efforts.
• Changes by the landfill host at the McCarty facility have led to elevated nitrogen in feedstock and reduced feedstock quantity.
• The Montauk Ag Renewables project faces challenges with feedstock collection and transportation optimization, utility interconnection, regulatory development, and offtake negotiations, which could delay revenue generation and increase costs.
• California Senate Bill SB-237, if passed, could cap LCFS credit prices at approximately $75/ton, potentially limiting profitability from these credits.

Future Outlook

The company anticipates increased production at existing projects as landfills expand. It expects the elimination of theoretical storage under EPA BRRR to not materially impact RIN revenue generation after pipeline injection. Significant revenue generating activities for the Montauk Ag Renewables project are expected to begin in 2026. Commissioning for the Bowerman RNG Facility, European Energy CO2 Facilities, and Tulsa RNG Facility is targeted for 2027, and the Rumpke RNG relocation project for 2028. The company expects to generate tax attribute benefits in its 2025 tax year from the Second Apex RNG Facility and in 2026 from Montauk Ag Renewables. It continues to evaluate the impacts of the Tax Reconciliation Act on tax credit expectations. The company believes it has sufficient cash flows from operations and borrowing availability to meet debt service and anticipated capital expenditures for the next 12 to 24 months.

Management Comments

• We continue to expect there will be a period where we have excess availability capacity after the Second Apex RNG facility is commissioned while the landfill host increases their waste intake.
• We continue to collaborate with the landfill host to mitigate impacts from wellfield extraction factors which could impact capacity utilization.
• We continue to review various alternatives related to interconnection opportunities as part of our considerations for offtake options with the understanding those alternatives may differ from initial development project assumptions, including physical and virtual and fixed interconnections.
• We have paused further capital expenditures related to the Blue Granite site while we consider all alternatives and continue discussions with the landfill host.
• We continue to incur capital expenditures for the Bowerman RNG project.
• We continue to target a commissioning start in 2027 for the Carbon Dioxide Beneficial Use Opportunity and began incurring capital expenditures for long lead items and design engineering in the second quarter of 2025.
• We expect to target a commissioning start in 2027 for the Tulsa REG Conversion to RNG and began incurring capital expenditures for long lead items in the second quarter of 2025.
• We continue to optimize the collection and transportation of swine feedstock from the collection farms to the centralized process location, including the removal of low energy content liquid waste.
• Given this ongoing optimization endeavor, we are increasing the range of capital investment required for the first phase of Montauk Ag Renewables to $180,000 $220,000.
• We continue to develop the opportunities with Montauk Ag Renewables and can give no assurances that our plans related to this acquisition will meet our expectations.
• We do not expect short term financial benefits from the Emvolon joint development venture nor a disruption to our operations.
• We expect to act as the RIN separator for the GreenWave joint venture and expect to receive separated RINs as distributions from the joint venture.
• We continue to review the impacts of the Tax Reconciliation Act on our expectations of IRC code section 48 investment tax credits under the Inflation Reduction Act, but we do not currently expect to transfer, as applicable, any tax attributes generated.
• We believe the impacts of the EPA BRRR reform and the 2024 proposed partial waiver of the 2024 RVO have temporarily impacted 2025 RIN purchase activity of RFS obligated parties.
• We expect this initial year impact of the EPA BRRR rule will increase our RINs unsold at the end of 2025.
• We continue to expect increased general and administrative expenses associated with our ongoing development of Montauk Ag Renewables in 2025.
• We do not anticipate approximately $1,780 thousand of non-linear discrete expenses will recur in the second half of 2025 as they relate primarily to annual preventative maintenance and gas processing maintenance.
• We do not anticipate approximately $1,399 thousand of discrete expenses primarily associated with our Bowerman facility will recur in the second half of 2025 as they relate to non-linear annual preventative maintenance.
• We believe that our existing cash and cash equivalents, cash generated from operations, and credit availability under our Amended Credit Agreement would allow us to pursue and close on our identified strategic growth opportunities in addition to the previously discussed non-development and development capital expenditures.

Industry Context

The renewable energy sector, particularly biogas and RNG, is driven by growing public support, governmental incentives (RFS, LCFS), and environmental concerns. Montauk Renewables operates within this context, leveraging federal and state policies to monetize Environmental Attributes. The industry faces challenges from regulatory changes, such as the EPA's BRRR and proposed RFS volume reductions, and California's evolving LCFS rules, which can impact RIN and LCFS credit prices. The company's expansion into agricultural waste (livestock farms) aligns with a trend towards diversifying feedstock sources, as these offer more attractive Carbon Intensity (CI) scores. The focus on CO2 capture and green methanol production also reflects broader industry efforts towards carbon utilization and circular economy principles.

Comparison to Industry Standards

• The average PPA price of $48/MWh for the Montauk Ag Renewables project is in line with various Southeast U.S. power markets, which typically range from $40 $60/MWh.
• The value of LCFS credits for dairy farm projects is noted to be a multiple of those realized from landfill projects due to significantly more attractive CI scores, indicating the company's strategic move into agricultural waste aligns with higher-value opportunities within the LCFS program.
• The company's 30+ years of experience in landfill methane-fueled renewable energy projects positions it as one of the largest U.S. producers of RNG, suggesting a strong historical presence and operational expertise compared to newer entrants.
• The company's operating model, utilizing modular equipment for RNG processing, is described as nimble and more efficient than fossil-fuel equivalents, implying a competitive advantage in operational flexibility and cost-effectiveness within the renewable energy production landscape.

Management Changes

Corporate Governance

Legal Proceedings

• The company and its subsidiaries are not currently a party, nor is their property subject, to any material pending legal proceedings.

Related Party Transactions

• A loan to Montauk Holdings Limited (MNK), an affiliate, with a current principal balance of $10,690 thousand, due December 31, 2033, secured by 976,623 shares of the company's common stock held by MNK.
• Consolidation of MNK as a Variable Interest Entity (VIE) on December 31, 2024, due to the company becoming its primary beneficiary after a modification of the TIA and repayment of the RP47 Loan on MNK's behalf.
• Repayment of the RP47 Loan of approximately $650 thousand (11,713 Rand) on MNK's behalf in March 2025, as MNK did not have sufficient funds.
• A long-term immaterial lease signed in December 2023 with a North Carolina landowner, who was subsequently hired as an employee in September 2024 to assist in procuring additional long-term leases for feedstock collection.

Stakeholder Impact

• **Shareholders**: Negative impact due to net loss, decreased operating income, and lower Adjusted EBITDA. Potential for dilution from future capital raises (debt) and uncertainty regarding the share repurchase program. Regulatory changes and project delays could affect future profitability and share value.
• **Employees**: One employee termination resulted in accelerated stock compensation expense. Ongoing development projects may create future employment opportunities.
• **Customers**: Stable RNG and Renewable Electricity production, but changes in RIN and LCFS markets could affect pricing and availability of Environmental Attributes.
• **Suppliers**: Increased capital expenditures for new projects (e.g., Montauk Ag Renewables, Bowerman, Tulsa, Rumpke relocation) indicate increased demand for equipment and services.
• **Creditors**: Increased long-term debt and revolving credit facility utilization, though the company remains in compliance with financial covenants. Cash flow from operations increased, but net cash used in investing activities is substantial.

Next Steps

• Continue to collaborate with the Apex landfill host to mitigate impacts from wellfield extraction factors.
• Review various alternatives for the Blue Granite RNG Project, including interconnection opportunities and producing energy other than RNG, with further capital expenditures paused.
• Continue incurring capital expenditures for the Bowerman RNG Project, targeting commissioning in 2027.
• Continue engineering design and incur capital expenditures for long lead items for the Carbon Dioxide Beneficial Use Opportunity, targeting first delivery in 2027.
• Continue incurring capital expenditures for long lead items for the Tulsa REG Conversion to RNG project, targeting commissioning in 2027.
• Continue optimizing feedstock collection and transportation for Montauk Ag Renewables, with significant revenue generating activities expected to commence in 2026.
• Contract with additional farms to secure feedstock sources for future production processes at Montauk Ag Renewables.
• Continue mitigation efforts related to wellfield environmental factors at the Rumpke and Apex facilities.
• Continue working with the McCarty landfill host to address elevated nitrogen in feedstock and reduced feedstock quantity.
• Continue incurring capital expenditures for long lead time equipment for the Rumpke RNG relocation project, targeting commissioning in 2028.
• Monitor and evaluate the impacts of the Tax Reconciliation Act on tax attributes and financial statements.
• Potentially purchase shares under the authorized $5,000 thousand Share Repurchase Program, as determined by the Repurchase Committee.

Key Dates

Recommendation

While Montauk Renewables is actively pursuing significant growth opportunities in RNG and CO2 capture, evidenced by substantial capital expenditures and new project commissions, the immediate financial performance is concerning. The shift to a net loss, decline in operating income and Adjusted EBITDA, coupled with lower realized RIN prices and project delays (e.g., Blue Granite), indicate operational headwinds. The increased debt also adds a layer of risk. However, the long-term strategic initiatives, potential tax benefits from the Inflation Reduction Act, and the company's established position in the renewable energy sector suggest future upside. A 'hold' recommendation is appropriate as investors should monitor the execution of these large-scale projects, the stabilization of RIN prices, and the company's ability to return to profitability before considering a 'buy' or 'sell' position.

Keywords

Renewable Natural Gas, RNG, Renewable Electricity, SEC Filing, 10-Q, Environmental Attributes, RINs, LCFS, RECs, Biogas, Landfill Gas, Anaerobic Digestion, Carbon Intensity, Clean Energy, Sustainability, Energy Transition, Financial Performance, Capital Expenditures, Project Development, Regulatory Impact, Methane Capture