Indicative planning tools for sizing a system and estimating savings ahead of a formal quotation. All assumptions are adjustable and all calculations run locally in the browser. Nothing is stored or transmitted externally unless you request a copy of the results by email.
Indicative estimates for system sizing, savings and payback. All inputs are adjustable and results update as the sliders move.
Standards guidance and technical terminology for project planning and procurement.
Adjust the inputs to model a specific system. Each parameter is defined below, and all underlying assumptions are visible and editable.
Indicative estimate for early-stage planning. Not a formal quotation.
The rated capacity of the solar array in kilowatts. Residential systems typically range from 6 to 13 kW; commercial and industrial installations commonly range from 50 to 500 kW.
The proportion of generated energy consumed on site rather than exported. This is the principal determinant of financial return: in Queensland, self-consumed energy avoids an import cost of approximately 30c per kWh, while exported energy earns approximately 6c. Sites occupied during daylight hours typically achieve 70 to 90 percent; unoccupied residential premises typically achieve 20 to 40 percent. Battery storage increases this figure.
The underlying assumptions used in this calculation. Default values reflect conservative figures for South East Queensland and may be adjusted to match a specific quotation, tariff or location.
The equivalent number of hours of full-intensity solar irradiance in an average day, averaged across the year. This is not the same as daylight hours. South East Queensland averages approximately 4.5 hours, tropical North Queensland 5 to 5.5, with lower figures in southern states.
The allowance for real-world losses from temperature, soiling, cable resistance and inverter conversion. The standard industry planning figure is 0.80, or 80 percent.
The retail cost of imported grid electricity per kWh, commonly 30 to 45c in Queensland. Each unit of self-consumed solar generation avoids this cost. The applicable rate is shown on a recent electricity account.
The feed-in tariff credited for exported generation. It is substantially lower than the import cost, which is why self-consumption and storage deliver greater value than export.
The installed capital cost per kilowatt, used to calculate payback. Actual pricing varies considerably by system type and site conditions; substitute a quoted figure where available.
Assumed annual escalation in electricity prices, applied to the long-term projections. Set to zero to exclude tariff escalation.
Updates as inputs are adjusted
The sum of avoided import costs and export credits.
The period required for accumulated savings to recover the capital cost.
Long-term projection
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Indicative estimates for early-stage planning only. Actual performance depends on roof configuration, orientation, shading, tariff structure, equipment selection and installation quality. This does not constitute a quotation or financial advice. Neboda can develop these figures into an engineered proposal.
Battery storage converts exported generation into avoided import cost. Adjust the inputs to model a specific system at residential or commercial scale. All assumptions are visible and editable.
Indicative estimate for early-stage planning. Not a formal quotation.
Applicable at any scale. Residential systems typically range from 5 to 20 kWh, commercial and industrial systems from 50 to 600 kWh. The underlying economics are identical.
The usable energy capacity of the system in kilowatt-hours. Residential systems typically range from 10 to 20 kWh; commercial and industrial systems from 50 to 600 kWh or greater. Larger capacity shifts a greater proportion of generation into evening consumption.
The number of full charge and discharge cycles completed daily. One cycle represents charging from solar and discharging across the evening peak. Residential systems with adequate generation typically achieve approximately one cycle per day; commercial systems with managed dispatch may achieve more. Utilisation is directly proportional to return.
The proportion of nameplate capacity available for use. A reserve is maintained to limit degradation. Modern systems typically permit 90 to 100 percent depth of discharge; refer to the manufacturer specification.
The underlying assumptions used in this calculation. Default values reflect current Australian market figures and may be adjusted to match a specific quotation, tariff or site.
The retail cost of imported grid electricity, typically incurred during the evening peak when the battery discharges. Each unit supplied by storage avoids this cost. Commonly 30 to 45c per kWh in Australia.
The feed-in tariff forgone by storing generation rather than exporting it. The differential between this rate and the import tariff represents the value captured per unit stored.
The installed capital cost per kWh before rebate. Australian residential systems commonly range from $600 to $1,000 per kWh; larger systems from $440 to $600. Substitute a quoted figure where available.
The federal Cheaper Home Batteries Program applies a tiered discount based on usable capacity. Since 1 May 2026 the first 14 kWh receives the full rate, 14 to 28 kWh receives 60 percent of it, 28 to 50 kWh receives 15 percent, and capacity above 50 kWh receives nothing. The rate shown is the first-tier value, currently around $252 per usable kWh, and it steps down every six months in January and July. The program covers systems from 5 to 100 kWh. Eligibility: the battery and inverter must both appear on the Clean Energy Council approved product list, installation must be supervised on site by an installer accredited with Solar Accreditation Australia, and grid-connected systems must be capable of joining a virtual power plant, although joining one is optional. Off-grid systems are exempt from the VPP requirement.
The assumed service life before replacement. Modern LFP systems typically carry a ten-year warranty. Used to calculate cumulative savings across the asset life.
Updates as inputs are adjusted
Energy shifted multiplied by the differential between import and export rates.
Capital cost and payback
Across service life
Cumulative savings across the assumed service life. Figures are undiscounted.
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Indicative estimates for early-stage planning only. Actual performance depends on generation profile, load pattern, tariff structure, achieved cycling, equipment selection and installation. This does not constitute a quotation or financial advice. Neboda can develop these figures into an engineered proposal.
Pairing storage with a diesel generator allows the generator to operate at its efficient load point while stored energy serves the remaining demand. This reduces fuel consumption, runtime and emissions. All assumptions are visible and editable.
Indicative estimate for early-stage planning. Not a formal quotation.
Applicable to generator-supplied sites including construction, mining, remote operations, events and off-grid facilities, from small units to prime-power sets.
The rated capacity of the generator in kVA. Small sites and events typically operate 10 to 50 kVA units; construction, mining and industrial sites commonly operate 100 to 1000 kVA.
Current daily operating hours. Sites operating during working hours typically run 10 to 14 hours; remote and prime-power sites may operate continuously.
The proportion of fuel consumption avoided by hybrid operation. Rather than running inefficiently at low load, the generator operates at its optimal load point, charges the battery, then shuts down while storage serves the site. Reported results typically range from 30 to 60 percent. The default is conservative.
The underlying assumptions used in this calculation. Default values reflect current Australian market figures and may be adjusted to match a specific site, fuel price or generator.
Average load factor as a proportion of rated capacity. Most sites operate at 40 to 60 percent, a range in which specific fuel consumption is materially worse than at optimal load. This inefficiency is the principal opportunity addressed by storage.
Fuel consumption per kVA of rated capacity per hour at full load. The standard planning figure is approximately 0.20 litres. Actual consumption scales with load rather than rated capacity alone.
Delivered fuel cost per litre. The national retail average is approximately $1.90, with regional and remote sites frequently exceeding $2.40. Bulk delivery may achieve lower rates.
Reduced runtime extends service intervals and overhaul periods. Industry figures indicate approximately 35 percent reduction. Applied proportionally to the runtime reduction. Set to zero to exclude.
Combustion of one litre of diesel releases approximately 2.68 kg of carbon dioxide. Used to calculate avoided emissions. This is a standard reference figure.
Updates as inputs are adjusted
Current consumption reduced by the specified fuel saving.
Runtime and maintenance
Applicable to decarbonisation targets and Scope 1 emissions reporting.
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Indicative estimates for early-stage planning only. Actual savings depend on load profile, generator condition, storage configuration and dispatch strategy, fuel cost and site conditions. This does not constitute a quotation or financial advice. Neboda can develop these figures into an engineered proposal.
Calculates emissions avoided through reduced grid electricity or diesel consumption. Applicable to sustainability targets, tender submissions and Scope 1 and 2 reporting.
Indicative estimate for planning and internal reporting. Not a certified carbon audit.
Select the source being reduced. Grid electricity covers consumption avoided through solar or storage and is reported under Scope 2. Diesel fuel covers combustion avoided in generation and is reported under Scope 1. Each may be calculated separately.
Annual grid electricity avoided, in kilowatt-hours. This figure may be taken from the annual generation or saving output of the solar or battery calculators, or from an existing energy plan.
The emission factors applied in this calculation. Default values reflect standard Australian figures and may be adjusted where a different state factor or reporting framework applies.
Emissions released per unit of grid electricity. The factor varies by state according to generation mix. Approximately 0.70 is a reasonable national working figure, with higher values in coal-weighted grids including Queensland. Formal reporting should apply the published state factor.
Combustion of one litre of diesel releases approximately 2.68 kg of carbon dioxide. This is a standard reference figure unless a reporting framework specifies otherwise.
Updates as inputs are adjusted
Consumption avoided multiplied by the applicable emission factor, expressed in tonnes of CO2 equivalent.
Comparative equivalents
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Indicative estimates for planning and internal reporting only. Emission factors vary by state, reporting year and framework. Formal disclosures should apply the factors specified by the relevant framework, for example the National Greenhouse Accounts. This does not constitute a certified carbon audit or financial advice.
Compares three configurations: solar alone, solar with storage and solar with storage and diesel offset. Inputs are entered once and applied across all three, showing annual saving, capital cost and payback for each. The shortest payback is highlighted.
Indicative comparison for early-stage planning. Not a formal quotation.
The rated capacity of the solar array, applied across all three configurations.
The storage capacity applied in the two configurations that include a battery.
Current annual diesel expenditure. Applied only to the third configuration. Set to zero where no generator is in use.
Shared assumptions applied across all three scenarios, consistent with the other calculators. Values may be adjusted as required.
Equivalent hours of full-intensity irradiance per average day. Approximately 4.5 for South East Queensland.
Standard allowance for system losses.
Retail cost of imported electricity, avoided by each self-consumed unit.
Credit received for exported generation.
Proportion of generation consumed on site without storage. Lower where premises are unoccupied during daylight hours.
Proportion of generation consumed on site once storage shifts supply into the evening.
Installed capital cost per kW of solar.
Installed capital cost per kWh of storage, net of rebate.
Proportion of diesel expenditure avoided in the third configuration.
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Indicative estimates for early-stage planning only. Actual outcomes depend on load profile, tariff structure, site conditions, equipment selection and system configuration. The highlighted configuration is determined by payback period alone and does not account for resilience, emissions or other benefits. This does not constitute a quotation or financial advice.
A top-down estimate of the reduction achievable through combined solar, storage and efficiency measures, calculated from current expenditure. All assumptions are visible and editable.
High-level estimate for early-stage planning. Not a formal quotation or energy audit.
Average monthly electricity expenditure, taken from a recent invoice.
The period of principal consumption. Solar delivers materially greater value to operations running during daylight hours, such as offices, workshops and retail, as generation is consumed directly. Operations weighted toward night-time consumption depend more heavily on storage.
The parameters applied in this calculation. Default values are conservative and may be adjusted to reflect specific circumstances.
The proportion of expenditure typically offset by an appropriately sized solar array for a daytime operation, commonly 20 to 40 percent. Adjusted automatically by the operating profile selected.
The additional proportion captured by storage through evening supply and reduction of peak demand charges, typically 10 to 20 percent.
The proportion avoided through demand reduction measures including lighting, HVAC controls, energy management systems and building envelope improvements, commonly 5 to 15 percent.
Assumed annual escalation in electricity prices, applied to the ten-year projection.
Updates as inputs are adjusted
Combined saving across all three measures, as a proportion of current expenditure.
Long-term projection
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A high-level, top-down estimate for early-stage planning only. Actual savings depend on load profile, tariff structure, roof and site characteristics and equipment selection. A site assessment is required before any commitment. The percentages applied are indicative and vary considerably between operations. This does not constitute a quotation, energy audit or financial advice. Neboda can develop these figures into an engineered proposal.
An orientation to the standards and approvals that apply to Australian energy installations. Select the installation type and connection arrangement to see which standards, network conditions and rebate requirements are relevant.
Select the closest match.
Standards do not vary between states. Network operator conditions do, and these commonly determine whether a system is approved.
The distribution network service provider, shown on the electricity account and determined by location rather than by retailer.
This overview covers the requirements Neboda assesses when evaluating products and suppliers. Talk to us about any specific application.
Discuss your projectIndicative guidance only, current as at July 2026. Standards are subject to amendment, network conditions change and this overview does not address every requirement that may apply to a given site. It does not constitute compliance certification, electrical design or legal advice. Current requirements should be confirmed with a licensed installer, the relevant network operator and the applicable standard before proceeding. Electrical installation work must be carried out by a licensed electrician, and grid-connected work requires network approval prior to energisation.
Definitions of the terms used in quotations, datasheets and network documentation.
If a term is not covered here, contact us and we will add it.
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