Montauk’s swine-waste biogas and the next test for returns

The next test for U.S. biogas returns is whether a project still works when a large investment tax credit cannot be assumed. Montauk Renewables’ $200 million swine-waste facility in North Carolina shows what that takes: a dependable farm collection network, a contracted buyer for each output, and enough value retained after collection, processing, and financing costs.

Montauk Renewables’ opening of a $200 million swine-waste facility in Sampson County, North Carolina, is more interesting than a new energy plant reaching the ribbon-cutting stage. It brings together farm-level collection, a converted industrial site, power sales, renewable natural gas, and biochar in one project. It is a useful case for asking what U.S. biogas development will need to look like when a large investment tax credit cannot be assumed.

Bioenergy Insight reported the September 2026 opening of the facility in Turkey, North Carolina. Montauk chief executive Sean McClain said the company had long-term agreements with more than 80 farming locations, providing access to more than 415,000 hog spaces targeted for the first phase. Those numbers describe a supply network, not simply the size of a plant. The collection system has to reach farms, deliver usable material consistently, and support a process that can sell its outputs for years.

Montauk’s development timetable suggests the project may be among the earlier biogas investments positioned to benefit from federal investment credits. Its project-specific tax position has not been publicly established in the sources cited here. The more valuable question is what a future project must prove if it cannot rely on a comparable capital benefit.

Swine waste is the starting point, not the whole product

The Turkey facility repurposes a former distribution center to process material from nearby hog farms. Montauk’s 2024 investor materials describe collection equipment at contracted farms and stages of solids concentration both on the farm and at the Turkey site. The September opening report describes electricity, renewable natural gas, and biochar as outputs. Montauk’s annual report says its patented reactor process produces biochar and that it expected renewable power generation to supply most of the project’s production revenue.

That distinction matters. Montauk is often discussed alongside manure digesters, but its North Carolina project has a specific collection and conversion design. It should not be treated as interchangeable with every on-farm anaerobic digester. What it shares with other biogas projects is the commercial difficulty of making a diffuse waste stream dependable enough to support an expensive industrial asset.

At the farm, the material is a handling problem. For the plant, it is feedstock. For the buyer, it becomes electricity, gas, an environmental attribute, or a usable soil product. Value has to be created at each handoff. Long-term farm agreements matter only if the collection process can deliver the quantity and quality the facility was designed to use. A technically successful conversion system does not solve a costly or unreliable collection network.

Biochar also changes the story. Montauk told shareholders it expected biochar sales to add a commodity revenue stream less directly tied to federal and state environmental-attribute programs. State senator Brent Jackson said at the opening that the material could improve soil nutrient and water retention. That is a prospective product case, not proof of a particular realized price or crop outcome. The investment case still depends on consistent specifications, handling costs, and customers who will pay for the product.

The value of a buyer on the other side

Montauk did not build its North Carolina project around a vague expectation that somebody would want renewable energy. In 2023 it announced a 15-year agreement with Duke Energy for electricity and associated swine-waste renewable-energy certificates from the proposed facility. The company has also discussed North Carolina’s treatment of swine-waste credits. Those arrangements link the plant to an identifiable market, although policy-dependent revenue still has to be evaluated against changing rules and prices.

For a $200 million reported investment, a firm buyer relationship can matter as much as a strong process yield. It gives investors a basis for estimating who pays, for what, and under which terms. It does not erase construction risk, operating risk, or exposure to market changes. Montauk’s 2025 results reported an approximately 29% decline in its companywide average realized renewable-fuel credit price compared with 2024. That figure is not a return calculation for the Turkey facility. It is a concrete reminder that an environmental-attribute price can move even while a plant continues to operate.

A durable project therefore needs more than a list of possible products. It needs a commercial case for each material revenue source: the electricity or gas buyer, the waste-handling customer, the biochar purchaser, and the party entitled to each environmental attribute. Those relationships have different contract lengths, price risks, and performance obligations. Adding them together in a spreadsheet is easier than making them hold through an operating cycle.

Vanguard shows a different route to the same commercial question

Vanguard Renewables and TotalEnergies are developing a different kind of network. Their 2024 joint-venture announcement described projects combining food and beverage waste with dairy manure to produce renewable natural gas. The partners said they intended to advance ten projects into construction and might consider a broader pipeline of about 60. Vanguard’s stated goal at the time was more than 100 commissioned RNG projects by the end of 2028. These were plans and potential projects announced in 2024, not a count of completed facilities today.

The pipeline has produced operating examples. In April 2026 Vanguard reported three completed facilities in Wisconsin and Virginia with nearly 870,000 MMBtu of combined annual RNG production capacity. The gas supplies AstraZeneca’s U.S. research and manufacturing operations under a corporate arrangement. Marc de Lataillade, TotalEnergies’ vice president for biogas, described the connection between production and "committed corporate demand" as a central part of those projects.

Vanguard’s model links the need to manage food waste, access to farm sites, gas production, and a corporate buyer. Montauk’s Turkey project links swine-waste handling, a power buyer, gas, and biochar. The technologies and output mix differ. The common investment question is whether enough value is contracted, delivered, and retained at the project level after collection, processing, transport, operations, and financing costs are paid.

An April 2026 company announcement said the three Vanguard facilities also use depackaging systems to handle food and beverage waste. That is a useful contrast with Montauk’s farm collection challenge. Feedstock is not merely an available tonnage within driving distance. Its form, contamination, seasonal pattern, preprocessing requirements, and delivered cost shape the entire business.

What changes as the 2028 window narrows

For many earlier biogas developments, the end of 2028 is a meaningful investment-credit planning milestone. It is not a universal legal expiration date for every biogas credit. Treasury and IRS guidance makes that distinction, but the detailed tax rules are not the point of this article. The commercial implication is that a project expecting a material capital benefit faces greater uncertainty as the window narrows, while newer projects may have to earn adequate returns without that benefit at all. We have no basis to say that Montauk, Vanguard, or any specific facility cited here is racing to meet a particular credit deadline.

That shift will separate projects with resilient operating businesses from projects that work only while a subsidy fills a capital gap. An ITC can improve a development case. It cannot keep farm collection cheap, make a reactor run reliably, guarantee a biochar market, or turn an uncommitted buyer into a bankable contract. As the assumption of an investment credit becomes less dependable, those operating questions take more of the weight.

What must be true for returns to work without a large ITC

The feedstock network must remain economical at full scale. More contracted farms can spread fixed costs and support throughput, but they also add collection routes, equipment, maintenance, and coordination. The important figure is not the waste available in the region. It is the volume the facility can actually receive and process at a delivered cost the product revenues can carry. Montauk’s reported access to more than 80 farms is promising because it addresses supply concentration, but access alone does not tell us the project’s collection cost or operating margin.

The plant must turn that supply into saleable output consistently. Nameplate capacity is not a cash-flow statement. Variations in manure solids or food-waste composition can alter yield and throughput. Equipment downtime can reduce the volume sold while labor, debt service, and other fixed costs continue. A project seeking strong returns without a capital credit has less room for a prolonged ramp-up or recurring performance losses. The early months of production matter because they reveal whether a development model survives contact with its real feedstock.

Buyers must pay enough for dependable service and products. A large RNG project cannot rely entirely on the idea that low-carbon gas will always command a premium. An electricity plant needs a credible power buyer and an understood path for its renewable attributes. A biochar producer needs a market that accepts the product’s actual specifications, not just a theoretical agricultural use. Waste-processing fees may add value where customers need reliable disposal or recycling, but their amount and durability depend on the local market. The strongest projects can point to counterparties and contract terms rather than a stack of assumed spot prices.

Policy exposure must be priced as risk, not treated as permanent margin. State renewable-energy certificates and transport-fuel attributes may provide substantial revenue in particular markets. They also depend on rules, eligibility, trading conditions, and buyer demand. Montauk’s decision to discuss biochar as a commodity revenue stream shows why product diversity matters: an output sold for practical use could balance some exposure to program-linked prices. Diversification only helps if the additional product has genuine demand and its own logistics work.

Capital spending must match the revenue base. Montauk’s reported $200 million outlay is a reminder of the scale involved. For a future project with no comparable investment credit, a larger share of that capital must be repaid through operating cash. The required prices, utilization, and contract duration become less forgiving. Some concepts may need a smaller first phase, a different site, a lower-cost interconnection, shared collection infrastructure, or a partner that values the waste-management service enough to commit. These are possible commercial responses, not descriptions of changes Montauk has announced.

The environmental case must survive scrutiny. A waste project creates value by solving a real handling problem and delivering useful outputs. Farm partners and neighboring communities will judge odor, truck traffic, water management, and local effects alongside any emissions claim. If the project’s environmental benefit depends on an assumed baseline or a future use of its products, investors and buyers should understand that dependency. Long-term returns require the facility to remain a good neighbor and a reliable operator, not just to win support during development.

None of these conditions is novel. What changes without a large capital credit is the tolerance for leaving them unresolved. The construction budget, supply network, product market, and operating plan must reinforce one another early enough for capital providers to believe the expected cash flow.

A more selective next wave

The U.S. biogas market has large waste streams and established reasons to keep developing projects. Montauk demonstrates one way to assemble a swine-waste supply network around power, gas, and biochar. Vanguard demonstrates another way to connect organics processing and farm partnerships with a committed gas customer. Neither is evidence that every proposed facility will earn the same returns, and neither company’s public announcements disclose the project-level economics needed to make that judgment.

The next wave will likely be more selective. Projects with dense, dependable feedstock, controllable collection costs, proven conversion performance, durable buyers, and revenue that survives weaker attribute prices can still make a case. Projects that require a large, uncertain credit to compensate for poor logistics or uncontracted sales will struggle to attract capital. That is Sharon Creek’s development view, not a prediction about any named facility.

For a broader framework on how feedstock, site, buyer, and capital risks fit together, read What Makes a Waste-to-Fuel Project Financeable? and When Feedstock Variability Becomes a Financing Risk.

Montauk’s swine-waste project and the next test for biogas returns