Build the next opportunity around your operating plant.

Establish the baseline

Gather gas flow, composition, operating hours, current energy use, maintenance records and contractual commitments. Identify which volumes are genuinely available. Heat supporting digestion and electricity used on site are valuable services; they should not disappear from the economics when a new sales opportunity is assessed.

Compare complete configurations

Consider keeping direct use, upgrading some or all available gas, and recovering compatible co-products. Compare capital, downtime, operating costs, approvals and customer requirements. An upgrade can improve product value without increasing the underlying amount of biogas produced.

Integrate modular equipment carefully

A defined equipment package may make phased development easier to assess. Confirm site layout, utilities, minimum throughput, controls, maintenance access and commissioning requirements. Include integration work and contingency in the budget rather than treating the module purchase price as total installed cost.

Develop co-products alongside the gas route

CO₂ separated during upgrading can be assessed for recovery. Digestate treatment can be reviewed against agricultural demand. Not every plant has a suitable CO₂ stream or profitable outlet. Processing, storage, product qualification and delivery should develop alongside buyer conversations.

An Australian integration example

Malabar combines wastewater-derived biogas, upgrading and connection to a gas distribution network. Its project documentation is a useful starting point for examining interfaces between the host facility, gas processing and network requirements. It does not provide a universal retrofit cost or return. [[ Australian Renewable Energy Agency (ARENA), Malabar Biomethane Injection Project ](https://arena.gov.au/projects/malabar-biomethane-injection-project/)]

Prepare the upgrade brief

Record baseline output and costs, proposed changes, customers, utility requirements, permission variations and unresolved evidence. This allows developers and financiers to assess incremental economics with any proposed support shown explicitly, rather than assuming that unsupported viability must already exist.

Frequently asked questions

Can every AD plant add profitable CO₂ recovery?

No. Stream quality, available flow, integration, customer demand and net returns determine suitability.

Does upgrading create more methane?

It concentrates and treats methane already in the gas. Changes to feedstock or digestion are separate production interventions.

Should existing heat and power be retained?

Assess their value and operational role before deciding how much gas can be redirected.

Sources & References

• Australian Renewable Energy Agency (ARENA), Malabar Biomethane Injection Project

  Publication: Date not verified

  Observation period: Project record and linked commissioning/lessons reports

  Relevant page / section: Claim-level locator not yet verified

  Last link / title verification: 2026-10-11

  Publisher link checked; individual claims, costs and regulatory applicability still require review.

  High for configuration and documented interfaces; no universal retrofit economics

• Shelby Bioenergy, Shelby’s National Renewable Gas Policy consultation response

  Publication: 2026-10

  Observation period: October 2026

  Relevant page / section: Supplied company position

  Last link / title verification: Not verified

  Company position / supplied material, not independent evidence.

  Proposals and scenarios, not adopted policy or market offers.

• Shelby Bioenergy, Shelby research and calculator methodology

  Publication: 2026-10

  Observation period: Research cut-off 7 October 2026

  Relevant page / section: Research and calculation controls

  Last link / title verification: Not verified

  Company position / supplied material, not independent evidence.

  Selected sources, not a national asset census.