Your Electricity Development Pathway, VIC

Action plan

Confidence 0%

First: Perform a feedstock audit to convert cow numbers into actual dry-matter tonnage available for digestion.

Next: Screen the site against EPA Victoria permission pathways [VIC-2] and local DNSP grid capacity.

Then: Obtain technology quotes to establish CAPEX and internal parasitic load requirements.

Decision gate: Compare net electricity revenue against total operational costs to determine if the project meets the internal rate of return requirements before proceeding to full assessment.

Developing this pathway in VIC

Confidence 0%

Victoria presents a regulated environment for organic waste processing. Public records show 133 bioenergy-related registry records in the state, with 13 matching the manure and effluent pathway, including registered carbon projects like the Ellinbank Dairy Farm and Stanhope Bioenergy. Market context indicates that while Victorian biomass potential is noted in regional datasets [VIC-1], specific network injection capacity for gas or grid export capacity for electricity is highly localized.

Screen EPA permission requirements

• Why it matters for you: Processing organic waste requires specific environmental approvals that dictate site layout and cost.
• Evidence needed: Determination of whether the project falls under A07a (large) [VIC-3] or A07b (small) [VIC-4] categories.
• Next action: Submit a pre-lodgement enquiry to EPA Victoria regarding waste processing tiers.
• Who confirms it: EPA Victoria [VIC-2].

Confirm grid connection type

• Why it matters for you: Electricity and gas connections involve different infrastructure, costs, and lead times.
• Evidence needed: A preliminary network enquiry to the local Distribution Network Service Provider (DNSP).
• Next action: Identify the site-specific DNSP and request a capacity check for a 50-100kW export.
• Who confirms it: Local Electricity Distribution Network Operator.

Development status

Confidence 0%

The project is currently in the early identification phase. Modelled outputs (engine ecosystem-1.0.0) indicate a daily production potential of 1,329 kWh of electricity from 550 cows. This is a theoretical maximum based on 346.75 operating days per year and assumes 100% manure collection. While the user has declared the resource and state (VIC), the specific conversion plant and network connection points remain unresolved. Current comparisons suggest a candidate route of electricity, though alternatives such as 485 Nm³/day of biomethane or 86.8 kg/day of hydrogen exist within the same gas pool. Total commercial viability is not established as CAPEX, OPEX, and net energy yields after internal plant consumption are unknown.

Commercialisation screen

Confidence 0%

Commercial viability not established. The next task is to develop a CAPEX and OPEX budget to compare against the indicative electricity price of 0.1709 AUD/kWh. While the model suggests a recoverable CO2 volume of 587 kg/day, biogenic CO2 buyer prices are not verified on Shelby and should not be included in the base case. Furthermore, certificates (LGCs/VEECs) and government funding are excluded from this assessment. The value of digestate [VIC-5] as a fertilizer replacement remains an assumed benefit until a nutrient analysis is performed. The current focus must remain on the primary electricity revenue stream and potential behind-the-meter savings.

Your next pathway decisions

Confidence 0%

The primary resource is manure from 550 fully housed cows. While the model indicates 1,329 kWh/day, the actual available feedstock for conversion depends on the efficiency of the collection system and the moisture content of the effluent. Electricity is the selected candidate route; however, the model also identifies a BioLNG alternative of 344 kg/day and a Hydrogen alternative of 86.8 kg/day. A specific conversion technology has not been selected, meaning parasitic loads (the power the plant uses to run itself) are not yet subtracted from the 1,329 kWh/day output.

Assess net energy yield

• Why it matters for you: Gross electricity production does not equal saleable power; internal pumps and mixers reduce the final revenue.
• Evidence needed: Parasitic load estimates for a small-scale anaerobic digester and CHP unit.
• Next action: Define the conversion plant technology to determine net exportable kWh.
• Who confirms it: Technology provider or engineering consultant.

Verify feedstock availability

• Why it matters for you: Herd size alone does not guarantee gas yield; bedding type and washwater volume affect digester sizing.
• Evidence needed: Logged manure collection weights over a 30-day period.
• Next action: Conduct a feedstock audit to confirm the actual tonnage available for the digester.
• Who confirms it: Farm manager or resource owner.

Frequently asked questions

Can I sell the 587 kg/day of recoverable CO2?

While the model shows recoverable mass, commercial sale depends on purification costs and finding a local buyer; these prices are not verified on Shelby.

Is the 1,329 kWh/day a guaranteed production figure?

No, this is a modelled output. Actual production depends on gas yield, plant uptime, and engine efficiency.

Does this project automatically qualify for carbon certificates?

No, certificates and funding are excluded from this base case and require separate registration and method compliance.

How does digestate management affect the project?

Digestate must be managed according to EPA Victoria requirements [VIC-5], which may involve storage and application constraints.

Sources & References

www.energy.vic.gov.au

www.epa.vic.gov.au

www.epa.vic.gov.au

www.epa.vic.gov.au

www.epa.vic.gov.au

www.agig.com.au