The following is an example of a fully worked technical feasibility assessment in response to the sample task prompt from the task expert. In your typical case, if everything looks acceptable, you will not need to provide this much feedback. For the sake of this example, we included one way to address all the different technical components for a project with a feasible technical profile.
You should expect to spend 1 hour working on each feasibility assessment, so plan accordingly for an hour's worth of review and response.
Overall assessment
The scenario, as defined by inputs [1]–[20], is technically plausible for a single-family home in Austin, TX.
PV, storage, heat pump, and EVSE specs are all reasonable for a 2,200 sq ft home with the given load.
A few clarifications are suggested but there are no hard blockers from an engineering perspective.
I would be comfortable signing off on this scenario for use in Arden training, provided the tax expert’s rubrics stay aligned with the technical assumptions summarized below.
Additional Details:
Location and load
The address and coordinates [1], [2] place the home in a typical Austin residential neighborhood with good solar resource.
2,200 sq ft, built in 1995, with 18,500 kWh/year historic usage is a plausible consumption profile, especially with existing electric loads and some cooling demand.
Treating census tract 48453001919 [3] as an Energy Community [4] is a tax assumption; there is no engineering conflict.
No changes required for basic site or load description.
PV system [6] and annual generation [7]
PV size of 8.5 kW DC [6] is reasonable for a typical Austin single-family roof with a strong south-facing section and 30° pitch, assuming modern modules and adequate roof area.
Annual production of 12,750 kWh [7] implies roughly 1,500 kWh/kW-year, which is very plausible for Austin given high solar resource and reasonable system losses.
The sizing strategy [13] (“target ~70% of historic load while accommodating additional electrification”) is coherent: 12,750 kWh vs. 18,500 kWh baseline, leaving room for residual grid purchases and increased usage from heat pump + EV.
Optional clarifications (not required):
The prompt already notes that 1,500 kWh/kW-year is reasonable. You could add a brief note that this aligns with NREL PVWatts outputs for Austin, but this is more for flavor than necessity.
Battery system [8], [9]
A 13.5 kWh, 5 kW battery [8], [9] is essentially a “one-Powerwall-class” system. This is common in residential applications and is appropriate for:
Backup for short outages, and
Limited time-of-use arbitrage if Austin Energy tariffs incentivize shifting consumption.
Electrically, 5 kW continuous power is modest relative to a typical 200A service, especially if there is some form of load management.
Optional clarification:
If tax treatment of storage depends on charging behavior, you may optionally state in the prompt that the battery is primarily charged from PV, with grid-charging only as needed. This can help the tax expert and models reason more cleanly about storage ITC eligibility.
Heat pump [10] and EV charger [11]
COP 3.2 [10] is a reasonable seasonal efficiency for a modern air-source heat pump in central Texas. It is neither unrealistically high nor low.
An 11.5 kW Level 2 EV charger [11] is a standard upper-end residential EVSE rating (typically a 48A charger at 240 V).
Combining a 200A service with PV backfeed, battery, heat pump, and an 11.5 kW EVSE is plausible, but in real projects would require a proper load calculation and possibly:
Load management for the EVSE, or
Demand-management devices to avoid main-service upgrades.
The prompt already includes:
“A licensed electrician has verified that the 200A service can support the PV system, battery, heat pump, and 11.5 kW Level 2 EV charger without requiring a service upgrade, possibly using load management if needed.”
This is exactly the right way to keep the scenario self-contained and technically feasible.
No mandatory changes here.
Domestic Content assumption [12]
The assumption that approximately 90% of eligible equipment cost can qualify for Domestic Content [12] is plausible from an engineering perspective because it is primarily a procurement/documentation issue, not a design issue.
Nothing in the selected equipment (PV, inverters, racking, battery, heat pump, EVSE) is inherently incompatible with Domestic Content; it simply depends on choosing compliant manufacturers and tracking bills of materials.
Key engineering note:
The rubrics strongly (and correctly) require the tax answer to call out supplier documentation and safe harbor use. From an engineering perspective, that focus on documentation is appropriate and does not conflict with the technical setup.
Financial inputs [14]–[20]
Total installed cost of 65,000 USD [14] for PV + storage + heat pump + EVSE in 2026 is on the higher side but very plausible for a turnkey, high-quality project in a major metro area, especially if soft costs are significant.
Treating the full 65,000 USD as ITC-eligible basis is explicitly called out as a simplifying assumption. In real practice, basis allocation might be more nuanced, but for a training scenario this is acceptable.
Tax capacity 18,000 USD/year [19] and the “prefer ITC if risk-adjusted NPV ≥ PTC” preference [20] are purely financial/tax inputs and do not create any engineering conflicts.
No engineering changes are required for the financial setup.
Alignment with rubrics
Response Rubric:
PV size and energy production tolerances (±20%) are reasonable; they allow some rounding or modeling variance while still penalizing large deviations.
Requiring acknowledgment of storage, heat pump, and EVSE in the tax analysis is helpful; these are realistic technologies that affect load and economics.
Emphasis on Domestic Content documentation, Energy Community tract referencing, and PWA is consistent with how engineering and construction teams actually support tax positions.
Chain-of-Thought Rubric:
Asking models to compute approximate kWh/kW-year and compare to typical ranges is realistic and good practice.
Expecting reasoning about PV sizing in the context of electrification (heat pump + EV) is exactly how real engineers and developers think about system design.
Mentioning the 200A service and load-management requirements in the reasoning criteria is appropriate: it encourages basic electrical awareness without forcing a full NEC load calc.
I see no technical misalignment between the rubrics and the scenario.
Required vs. optional edits
Required before using this task:
None. From an engineering standpoint, the scenario and rubrics are acceptable as written.
Optional quality improvements (if you want to tighten the engineering flavor):
Storage charging assumption
Add one sentence in the prompt stating that the battery is configured to be primarily charged from PV, with limited grid charging, to make ITC eligibility assumptions more transparent for storage.
Roof and array detail
If you want to be extra explicit, you could add an approximate usable roof area or module count (for example, 20–24 modules at 400–425 W each) to show that 8.5 kW DC is well within roof capacity. This is not strictly necessary, but can help models avoid oversizing confusion.
Domestic Content nuance
Optionally note that real Domestic Content thresholds can vary by technology and that in this exercise, 90% [12] is assumed to be sufficient to clear those thresholds. This mirrors the tax rubric emphasis on safe harbors.
If you choose not to add these clarifications, I would still sign off on the task as a technically realistic training scenario.