Source & design basis
Document source energy, candidate host, load and baseline alternative. Bound magnetic loads, material duty, losses and thermal requirements.
NATIONAL ELECTRICITY · CASE-STUDY-INFORMED BUDGET · USD
National ambition.
A staged funding plan.
Separate the long-term rollout from the capital needed for the next decision.
View a case
Choose a scenario to update the CAD view, simulation controls, money dashboard and funding breakdown together. The original reference assumptions remain the default. Paybacks below are calculated scenarios, not guaranteed returns.
| Financial assumptions changed | CAPEX | Annual margin | Payback | Action |
|---|
Click an underlined operating-margin amount to open its itemized browser workbook. A project password is required. Workbook edits do not change this dashboard.
This is a funding scenario for generator-led mechanical-to-AC conversion, with magnetic–piezo development retained as the research program. It is not a national supply commitment or a price for the football-field CAD geometry. Published recovery projects inform cost allowances; they do not establish WegaWomb performance.
SELECTED ECONOMIC CASE · ASSOCIATED CONCEPT DESIGN
All price cases use the existing magnetic–piezo carousel concept below. Prices do not change geometry or qualify the financial unit's MW rating. The generator-led economic model is not a measured output prediction for this research CAD.
Drag the CAD to orbit; use its rotation, exploded-view, size and download controls. Geometry edits stay inside the CAD viewer and its downloads; they do not recalculate this financial case. The assumptions download includes a link that reopens this financial case. The CAD has its own separate geometry downloads.
National money dashboard
Where national CAPEX goes
Power-package allowance already includes plant equipment, plant engineering, construction and commissioning. Adders cover incremental national-network work, source connection/adaptation and non-EPC owner costs—not the same plant work again. Contingency applies once to that subtotal.
The source-connection allowance does NOT finance construction of a new primary energy source. Land acquisition, new primary-source plants, national storage/backup, financing and taxes are not fully priced. This is a scoped conversion-and-integration budget, not an all-in national power system.
What could change the result?
Compare published generation and wholesale references in KES, USD and GHS. Retail tariffs are not used to set these scenarios. The $120/MWh sale value remains a contract target, not a verified national market price.
Can we reach 10 years?
The new target pairs a $2,600/kW power package with $120/MWh electricity value: a 35% package-cost cut from the $4,000/kW comparison. It preserves energy output, source costs, network allowances, contingency and upkeep rates. The roughly 17-year comparison restores BOTH $4,000/kW and $120/MWh. Other edits can make either case better or worse; the calculated payback, not the case name, is the result.
Choose a case at the top of the page. Only the named financial assumptions change; every preview uses your current settings. Normal country links retain the original reference defaults.
The $2,600/kW target is an analyst-selected stretch budget, below the earlier $3,000/kW low case. DOE's April 2021 Table 4 estimated $2,500/kW for 5–20 MW organic Rankine recovery systems—a different, established technology. That historical analogue does not validate today's WegaWomb cost or national rollout. Confirm equipment, source integration and buyer contracts before treating either case as achievable.
The threshold includes CAPEX-linked upkeep: maximum capital = 10 × annual margin before fixed upkeep ÷ (1 + 10 × upkeep rate). It uses credited, source-constrained energy when both source limits are supplied. These are scenario bounds, not a confidence interval or a supplier ceiling. The national and 10 MW calculations assume source output can be curtailed to credited demand; they do not reproduce the single-unit AC dump-load operating case.
CLICK A CAPITAL AMOUNT TO TRACE ITS COSTS
Itemized capital breakdown
Priced rows reconcile to the selected total. Subtotals and totals are summaries, not extra costs. Equipment-level amounts without an allocation are identified as unpriced within the allowance; this is not a supplier bill of materials.
Back to money dashboard · Back to case comparisonsPUBLISHED ELECTRICITY COSTS · LOCAL CURRENCY → USD · CHECKED 8 OCTOBER 2026
What energy costs—not just retail tariffs
Separate production expense, utility procurement and wholesale market prices. They answer different questions and are not interchangeable country rankings. None establishes the price of WegaWomb's external mechanical input or a secured buyer contract.
Conversion: local currency per kWh ÷ local currency per USD = USD per kWh; multiply by 1,000 for USD per MWh. Price periods and exchange-rate dates are shown separately. Converting a historical observation at recent FX does not make it a current quote or adjust it for inflation.
Two costs still need a specific project
Input: usable shaft-work cost depends on the actual energy source, conversion losses, access agreement, maintenance and operating schedule. National electricity averages do not price otherwise-wasted motion. An electric motor test would also pay for motor losses.
Output: a buyer's negotiated price depends on location, delivery point, availability and contract terms. The under-10-year case still requires its $2,600/kW package target and $120/MWh electricity-value assumption; the roughly 17-year comparison still uses $4,000/kW and $120/MWh. Published costs below those prices do not secure either return.
The same framework, three markets
Historical electricity baselines; 55% means annual electricity coverage, not all energy or hourly reliability. Shared cost assumptions do not imply identical local tariffs, supply chains or permitting.
| Country | Baseline | Target | Build size | Capital scenario | Input required |
|---|
Comparison shows conditional requirements using each published demand baseline and shared engineering/cost settings; it does not apply the active country's optional source limits. The active country's manual demand edit affects its main dashboard only. Countries are alternative market scenarios, not a combined fundraising total.
LEVEL 2 · CONDITIONAL PROJECT FINANCE
One large demonstration project
Start with an industrial host that can document a real energy stream and use or buy the output. The reference target is one 10 MW AC project—not rows of tiny generators. Its rating and geometry must emerge from engineering; the funding model does not assign 10 MW to an existing CIPS device.
Project CAPEX is separate from company-development funding. It assumes a proven design and a matched source at the stated duty cycle. National source entries do not prove this individual host has an available source. Do not treat the initial raise as enough to build this project.
Labour and startup budget
Enable JavaScript to calculate local-currency and USD planning costs for Kenya, USA and Ghana.
LEVEL 1 · WHAT TO RAISE FIRST
Reference funding breakdown
A proposed 18-month development program to establish the source, conversion evidence, engineering package, host site and priced demonstration plan. One shared company program—not three separate country raises. This table retains the original reference allocation; the selected labour target and site-development reserve are shown in the startup plan above.
| Use of funds | Allowance | What it buys |
|---|
Company allowances are a bottom-up planning budget, not case-study invoices or a grant award. At the $3M reference, personnel assumes five loaded roles over 18 months. Editing the total scales all allowances; staffing and delivery must then be replanned. Compare local labour and startup costs above. No salary commitments or supplier orders are authorized.
Conversion evidence
Obtain independently reviewed loaded measurements, fatigue evidence and a coupled engineering model. Continue only if performance and safety gates are met.
Priced project package
Secure budgetary quotations, interconnection scope and host/buyer terms. Make the go/no-go decision for a separately financed large project.
Funding-room summary
An 18-month work plan is a proposed program duration, not a promise that national deployment or a 10 MW device will be achieved in that time.
REPORTED FACTS → PLANNING INFERENCES
What the case studies support
How those cases enter this budget
| Assumption | Starting value | Evidence / inference |
|---|---|---|
| Installed power package | $4,000/net AC kW; $3,000–$10,000 sensitivity | Analyst-selected current-USD planning allowances informed by historical industrial recovery projects and DOE estimates. Not an exact inflation-adjusted quote, not a validated WegaWomb cost curve. Historical source amounts retain their stated publication dates. |
| Fixed upkeep | 2.5% of total modeled CAPEX/year | IFC motivates the rate; applying it to the whole project is our planning choice. Incremental variable O&M starts at zero to avoid duplicating benchmark upkeep. |
| Capacity factor | 80%, including downtime | Editable scenario informed by—but not equal to—industrial utilization evidence. It is not 80% efficiency or a guarantee of source availability. |
| Net mechanical-to-AC conversion | 86% | Generic generator-led engineering assumption, inclusive of active auxiliaries and conditioning. Not a measured CIPS or WegaWomb efficiency; no thermal-to-mechanical conversion is hidden in it. |
| Source / electricity price | $20 / $80 per MWh | Illustrative mechanical-input cost and delivered electricity value, not local tariffs, contracts or case-study results. If heat is the source, the machinery and losses converting it to shaft work must be added upstream. |
| Network / source connection / owner / contingency | 15% / 20% / 5% / 25% | Separate analyst allowances. Country-specific grid projects below demonstrate material scope, but do not prove these percentages. |
| Life / discount / replacement | 25 years / 8% / 10% of package in year 12 | Planning cash-flow assumptions; not established equipment life, financing terms or a maintenance schedule. |
Infrastructure cannot be priced like a small inverter
Financial boundary and calculation method
Required AC capacity = annual target electricity ÷ (8,760 × capacity factor × delivery efficiency). Build size rounds up to whole financial units. Capacity factor already includes downtime. Net AC efficiency includes active auxiliary consumption; those losses are not added again. Unused annual capacity earns no automatic revenue. Required mechanical energy = credited delivered electricity ÷ (net conversion efficiency × delivery efficiency).
When BOTH source power and annual energy are supplied, they cap credited output and revenue. Blank source values mean unknown: national coverage remains a conditional requirement, not proven supply. Source acquisition and opportunity cost are paid through the entered mechanical-input price. Free magnetic energy is never credited.
Simple payback is total CAPEX ÷ positive annual margin. NPV discounts end-of-year operating cash flows and the specified replacement. Levelized cost includes capital, upkeep, source energy and replacement over delivered energy. The fully built fleet is assumed operational at year one; construction phasing, growth, debt, taxes, currency changes, storage, grid congestion, standby/startup energy and salvage are not modeled. This is not an investment return guarantee or a national financing plan.
NIST Handbook 135 (2025) supports the lifecycle-cost framework, not these technology prices. A shorter payback alone does not establish the best investment.