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	1	# PRSM Electrical Design Review — Session Rules
	2
	3	You are reviewing and validating the **electrical configuration** of an off-grid solar build.
	4	Read `HANDOFF.md` in this folder first — it is the authoritative scope and task list.
	5
	6	## The one rule that matters most
	7	**Never state a voltage, current, ampacity, string length, voltage-drop %, runtime, or kWh that you did not compute by running a script in `scripts/`.** If you need a number, write and run the Python first, then cite the script. Estimated or "about" numbers are not acceptable in the final design — this is a safety-relevant electrical design.
	8
	9	## Grounding stack (use, don't reinvent)
	10	- `vocmax` — NEC 690.7 cold-weather string sizing from NSRDB extreme temps. The binding constraint for max modules-in-series.
	11	- `nrel-pysam` (Pvwattsv8, `array_type=0`) or PVWatts V8 API — production / per-MPPT energy. Verify the API host (migrated to `developer.nlr.gov` 2026-05-29).
	12	- `pvlib` — independent IV/cell-temperature cross-check of the string result.
	13	- Plain Python for NEC 690.8 ampacity (125%×125% continuous + 310.15 temp/fill derates) and voltage drop. Encode and cite the NEC table you use.
	14	- `schemdraw` — render the SLD and wiring diagrams (PNG + SVG).
	15
	16	## Scope discipline
	17	- IN: panels (string config), wiring, OCPD, inverter config, battery wiring, grounding/labeling at SLD level, schematics.
	18	- OUT: structure, racking, foundations, trenching civil, pricing, permitting, incentives. The owner has the housing/mounting handled — do not factor it in.
	19
	20	## Locked hardware (do not re-litigate; see HANDOFF §3)
	21	Waaree 575W Grade B · ~8 kW active now · 1× EG4 6000XP · 1× Docan S3 16 kWh · off-grid · NE Vermont.
	22
	23	## Before designing
	24	Confirm the §4 inputs in HANDOFF (datasheet electricals, inverter limits, run lengths, NEC cycle, lat/lon). Ask the owner the run-length and AHJ-code questions up front. Flag any assumption you can't confirm from a datasheet.
	25
	26	## Output
	27	Write deliverables to `artifacts/` per HANDOFF §7. Every number traces to a script.

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	1	---
	2	title: PRSM Solar — Phase 2 Electrical Design (Handoff)
	3	project: PRSM
	4	type: session-handoff
	5	created: 2026-06-03
	6	for: a fresh Claude Code session
	7	scope: ELECTRICAL ONLY — final-state full-pallet array, inverter expansion, battery bank, wiring, diagrams. Housing/shed/fire-code EXCLUDED (flag only).
	8	builds_on: the completed & validated Phase-1 review in this same folder (artifacts/, scripts/, site.yaml, data/)
	9	---
	10
	11	# Handoff: Phase 2 Electrical Design for PRSM Off-Grid Solar
	12
	13	You are a fresh Claude Code session. **Phase 1 is already designed and validated** (see
	14	`artifacts/electrical-design.md`). Your job is to design the **final, full-build system
	15	state**: wire the remaining pallet panels to meet the real household load, expand the
	16	inverter and battery to match, re-validate every number, and render **final-state diagrams**.
	17	Same discipline as Phase 1: **every load-bearing number is computed by a script in `scripts/`**,
	18	never estimated. Reuse the Phase-1 scripts and grounding stack — do not start from scratch.
	19
	20	## 0. What Phase 1 established (your starting context — do not recompute, reuse)
	21	All computed and cross-checked; values live in `artifacts/results/*.json` and `site.yaml`:
	22	- **Module** Waaree Elite BiN-08-575: Voc 52.30 V, Vmp 43.86 V, Isc 13.87 A, Imp 13.11 A,
	23	β(Voc) −0.26 %/°C, 1500 V. **Hard rule: 7 modules/string MAX** (8S = 491 V at −40 °C+bifacial, unsafe).
	24	- **Inverter (Phase 1)** EG4 6000XP: 2 MPPT, 500 V abs / 480 V design / 385 V MPPT-track,
	25	17 A/MPPT, **8 kW PV usable (already maxed by Phase-1's 8.05 kW)**, 6 kW AC, 140 A batt discharge.
	26	- **Battery (Phase 1)** 1× Docan S3 16 kWh (12.86 kWh usable @ 80 % DoD): JK BMS 150 A trip /
	27	157 A cell-honest; **175 A Class-T + 2/0 Cu** battery cable; cold-charge handled by **separate
	28	propane heat** (not electrical).
	29	- **Conductors (Phase 1)**: PV 8 AWG (200 ft, 1.33 % Vd) · battery 2/0 · AC 8 AWG / 35 A 2-pole.
	30	- **Load (REAL, Hardwick Electric)** in `data/hardwick_usage.csv`: **12,237 kWh/yr · 33.5 kWh/day
	31	avg · summer-peaking (Aug 54.1 kWh/day, winter 26.6)** · ~$0.227/kWh · ~$2,779/yr.
	32	- **Production**: Phase-1 8.05 kW → 9,622 kWh/yr (79 % of load). **Full pallet 17.8 kW → 20,962
	33	kWh/yr (171 %, meets load in every season incl. Aug peak)** — computed in `scripts/09_phase2.py`.
	34	- **Phase-2 cost (estimate)**: remaining panels **$0** (already owned); lean ~$4.3–5.2K,
	35	recommended ~$7.8–9.2K. See `artifacts/results/09_phase2.json`.
	36	- **Environment**: main venv `~/.venvs/prsm-electrical` (py3.13); vocmax pinned venv
	37	`~/.venvs/prsm-vocmax` (py3.9). **NREL host: `developer.nlr.gov`** (nrel.gov failed; the
	38	scripts try both). `NREL_API_KEY` may still be unset — DEMO_KEY works for PVWatts.
	39
	40	## 1. What is IN scope (Phase 2, final state)
	41	- **DC array**: re-string the **full 31-panel pallet (17.8 kW)** across the expanded inverter's
	42	MPPTs, keeping cold-Voc ≤ design ceiling and **≤ 7 modules/series**. Combiner if needed.
	43	- **Inverter expansion**: design for **12 kW AC / ≥16 kW PV** — either **2× EG4 6000XP in parallel**
	44	or a **single EG4 18kPV** (owner picks; see §3). PV-to-inverter conductors, AC output + OCPD.
	45	- **Battery bank**: **2–3× Docan S3** in parallel — bank busbar/interconnects, per-pack vs bank
	46	Class-T fusing, discharge at 12 kW (~252 A bank), BMS comms for multiple packs.
	47	- **Wiring & overcurrent** for the whole final state (NEC 690.8, 310.15 derates, voltage drop).
	48	- **Grounding/bonding** (690.43/47) and **labeling** at SLD level for the final build.
	49	- **Final-state schematic renderings** (see §7).
	50
	51	## 2. What is OUT of scope (flag, don't design)
	52	- Battery shed / structure / racking / foundations / trenching civil.
	53	- **NFPA 855 / fire code** — at **3 packs (48 kWh)** the build crosses the residential threshold
	54	(detached non-combustible shed ≥10 ft, UL 9540 listing or AHJ hazard-mitigation analysis), and
	55	the **propane heater in a Li-battery enclosure** needs combustion-air/ventilation/separation.
	56	**Flag these as gates; do not engineer them.** (Swarm §4.)
	57	- Pricing beyond the Phase-2 estimate already produced; permitting; economics/payback.
	58	- Generator selection (Phase-1 infra; assume AC-IN to the inverter, 50 A pass-through, gen-assist on low SOC).
	59
	60	## 3. Locked + decisions you MUST confirm with the owner (ask up front)
	61	| Item | Status |
	62	|---|---|
	63	| Use the **remaining 17 pallet panels** (full 31 = 17.8 kW) | Locked (owner request) |
	64	| Meet the **12,237 kWh/yr** real load | Locked (data on file) |
	65	| **Inverter path** | **ASK**: (A) parallel 2nd EG4 6000XP (~$1,700, cheaper, 2× JK↔Pylontech-CAN comms) vs (B) sell 6000XP → single **EG4 18kPV** (~$3,500–3,700 net, single comms; Swarm §10 recommends for >10 kW). Real delta ~$1,900. |
	66	| **Battery count** | **ASK**: 2 packs (25.7 kWh usable, Swarm §6 min) vs 3 packs (38.6 kWh, ~1 day autonomy @ avg — but crosses NFPA 855). |
	67	| **Battery siting** | **ASK**: detached shed location (forced at 3 packs) → sets new inverter↔battery run length. |
	68	| **New run lengths** | **ASK**: array→new strings (where the 17 remaining panels sit), inverter↔added battery packs, any new trench leg. |
	69
	70	## 4. Inputs you MUST confirm before designing (don't assume)
	71	1. **EG4 18kPV datasheet** (if path B): MPPT count, max PV Voc, MPPT range, max input A/MPPT,
	72	max PV power, battery charge/discharge limits, AC output, integrated disconnect/RSD/AFCI.
	73	*(If path A, the 6000XP specs are already in `site.yaml`.)*
	74	2. **Docan S3 paralleling**: max packs in parallel on one BMS bus, bank comms (one master?),
	75	recommended bank fusing (per-pack Class-T vs single bank fuse) — confirm with the JK BMS docs.
	76	3. **New conductor run lengths** (§3) — one-way feet.
	77	4. **NEC cycle**: 2023 (confirmed Phase 1) — keep unless the AHJ has updated.
	78	If any can't be confirmed from a datasheet, **state the assumption and flag it** (as Phase 1 did).
	79
	80	## 5. Validation method — reuse the Phase-1 grounded stack
	81	**Rule (unchanged): no voltage/current/ampacity/string-length/kWh in the final design that a
	82	script didn't compute.** Extend the existing scripts; don't reinvent:
	83	- **String sizing** → `scripts/01_string_sizing.py` (+ `01b_vocmax.py`): re-run for the full
	84	pallet across the chosen MPPT topology. Cold-Voc ≤ 480 V, **≤ 7S**, hot/cold Vmp in window.
	85	- **Production** → `scripts/02_production.py` / `09_phase2.py` (full pallet already = 20,962 kWh/yr).
	86	- **Conductors** → `scripts/03_conductors.py` + `nec_tables.py`: re-size for 12 kW AC output
	87	(~50–63 A → bigger AC feeder/OCPD), more PV strings (combiner?), and the battery bank.
	88	- **Battery** → `scripts/04_battery.py`: bank discharge at 12 kW (~252 A), split across 2–3 packs;
	89	per-pack vs bank Class-T; C-rate per pack; autonomy at the real load (`08`/`09`).
	90	- **Load match** → `scripts/08_load_actual.py` + `09_phase2.py` (reuse `common.load_usage()`).
	91	- **NEC checklist** → `scripts/05_nec_checklist.py` for the final state (add 705/706 multi-pack notes).
	92	Each script prints inputs + the formula/NEC section + result, and dumps to `artifacts/results/`.
	93	Create a Phase-2 config — either extend `site.yaml` with a `phase2:` block or add `site-phase2.yaml`
	94	(module_count 31, inverter = chosen path, battery pack count) — keep `site.yaml` as the single source.
	95
	96	## 6. Diagrams — FINAL SYSTEM STATE (schemdraw → PNG + SVG)
	97	Extend `scripts/06_schematics.py`; write to `artifacts/phase2/`. All ratings trace to the calcs.
	98	1. **Final SLD** — full 31-panel array → DC disconnect/combiner → **expanded inverter (2× 6000XP
	99	or 18kPV)** → **2–3 Docan S3 bank** → critical-loads/main panel, **+ generator AC-IN**, with all
	100	OCPD/disconnect/conductor ratings and the rapid-shutdown note.
	101	2. **Final DC-string diagram** — all 31 modules grouped into strings across the MPPTs (label the
	102	stringing, e.g. how 31 panels map to 3 or 4 MPPTs at ≤7S), polarity, combiner, fusing.
	103	3. **Final battery-wiring diagram** — 2–3 packs in parallel: bank busbar, per-pack/bank Class-T,
	104	bank disconnect, cable gauge, multi-pack BMS comms (master/slave → inverter).
	105	Diagrams must match the computed numbers exactly.
	106
	107	## 7. Deliverables (write to `artifacts/phase2/`)
	108	- `phase2-design.md` — final-state validated electrical design, every number traced to a script.
	109	- `phase2-nec-checklist.md` — Art. 690 + 480/705/706/710 for the full build, computed evidence.
	110	- `phase2-bom.md` — added equipment (inverter, 1–2 batteries, wire, OCPD, fusing, combiner,
	111	busbar, lugs), quantities from the calcs, **panels $0 (already owned)**, cost estimates labeled.
	112	- `sld.{png,svg}`, `dc-strings.{png,svg}`, `battery-wiring.{png,svg}` — final state.
	113	- `phase2-open-issues.md` — inverter/battery decisions, NFPA 855 gate, datasheet gaps, assumptions.
	114
	115	## 8. Acceptance criteria
	116	- Full-pallet cold-Voc passes with margin, ≤ 7S, computed by `01`/`01b` (not estimated).
	117	- Every conductor (incl. 12 kW AC feeder + battery bank) has an ampacity calc with derates ≥ its
	118	corrected continuous current, and a voltage-drop figure within target.
	119	- Battery bank discharge at 12 kW is within per-pack BMS + inverter limits, shown numerically.
	120	- Full-pallet production vs the real load shown by season (already: meets all seasons).
	121	- Schematics match calc outputs exactly; NFPA 855 gate flagged.
	122	- No unverified number anywhere.
	123
	124	## 9. Working approach
	125	Confirm §3/§4 with the owner first (the **inverter choice drives everything** — ask it first).
	126	Then fan out per dimension (string / conductors+Vdrop / battery bank / NEC / diagrams), each calling
	127	its grounded script, then synthesize. Adversarially double-check the full-pallet cold-Voc string
	128	result. Keep the generator AC-IN and propane-heat assumptions explicit.
	129
	130	## 10. Reference docs (read for context)
	131	- **Phase-1 outputs (read first):** `artifacts/electrical-design.md`, `artifacts/nec-checklist.md`,
	132	`artifacts/bom-electrical.md`, `artifacts/open-issues.md`, `artifacts/results/*.json`, `site.yaml`,
	133	`data/hardwick_usage.csv`, and `scripts/` (01–09, `common.py`, `nec_tables.py`).
	134	- `../PRSM Solar Build - Key Decisions.md` — locked build decisions, Phase-2 phasing (§44/§64/§76/§108).
	135	- `../PRSM Solar Build - Swarm Review.md` — Phase-2 inverter path (§10), battery target (§6),
	136	NFPA 855 (§4), AC topology (§17), BMS comms caveat (§9).
	137	- `../Claude Code for Solar Design - Research.md` — grounding-stack rationale.
	138	- `HANDOFF.md` — the Phase-1 handoff (this is its sequel; mirror its rigor).

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	1	---
	2	title: PRSM Solar — Electrical Design Review (Handoff)
	3	project: PRSM
	4	type: session-handoff
	5	created: 2026-06-02
	6	for: a fresh Claude Code session
	7	scope: ELECTRICAL ONLY — panels, wiring, inverter, battery. Housing/mounting EXCLUDED.
	8	---
	9
	10	# Handoff: Electrical Design Review for PRSM Off-Grid Solar
	11
	12	You are a fresh Claude Code session. Your job is to **review and validate the electrical configuration** of the PRSM off-grid solar build, produce a corrected electrical design, and render schematic-style diagrams. Every load-bearing number must be **computed/validated with NREL-grade Python**, not estimated.
	13
	14	## 1. What is IN scope
	15	- DC PV array: module selection is fixed; you design **string configuration** (modules in series/parallel), per-MPPT assignment, and validate against the inverter's voltage/current window.
	16	- **Wiring & overcurrent**: PV source/output conductor sizing & ampacity (NEC 690.8), voltage drop across all runs, OCPD ratings, disconnects, combiner.
	17	- **Inverter** configuration: MPPT loading, PV-to-inverter conductors, AC output conductor + OCPD.
	18	- **Battery**: battery-to-inverter conductor sizing, overcurrent (Class-T fuse), BMS current limits, charge/discharge validation, runtime sanity check.
	19	- **Grounding/bonding** (690.43/690.47) and **labeling** (690.56/110.21) at SLD level.
	20	- **Schematic renderings** (see §6).
	21
	22	## 2. What is OUT of scope (do NOT spend effort here)
	23	- Ground-mount structure, racking, foundations, snow/wind load, trenching civil work — **the owner already has construction materials and the mounting handled.**
	24	- Panel procurement/pricing, freight, $/W optimization — already decided.
	25	- Permitting strategy, incentives, insurance — covered in other PRSM docs.
	26	- Whole-system cost budgeting.
	27
	28	## 3. Locked decisions (do not re-litigate)
	29	| Item | Decision |
	30	|---|---|
	31	| Architecture | DIY **off-grid** (no grid interconnection, no net metering) |
	32	| Panel module | **Waaree 575W Bifacial (Grade B)** — design anchor |
	33	| Active PV now | **~8 kW DC** (≈14 panels) into a single inverter; remaining pallet panels are future expansion, not wired now |
	34	| Inverter | **1× EG4 6000XP** (all-in-one off-grid, 8 kW PV cap, dual MPPT) |
	35	| Battery | **1× Docan S3**, 51.2V ~314Ah ≈16 kWh, JK 200A BMS |
	36	| Site | Rural Northeast Vermont (Northeast Kingdom) |
	37	| Renderings | **Python `schemdraw`** → SLD + string/battery wiring (PNG + SVG) |
	38
	39	## 4. Inputs you MUST confirm before designing (do not assume)
	40	These drive everything downstream. Pull from datasheets / ask the owner; do not invent.
	41
	42	1. **Waaree 575W datasheet electricals** — Voc, Vmp, Isc, Imp, **temp coefficient of Voc (%/°C)**, max system voltage (1000/1500V). *(The exact Waaree 575W series, e.g. the bifacial 144-half-cell line, must be matched — there are multiple 575W SKUs.)*
	43	2. **EG4 6000XP PV input limits** — max PV open-circuit voltage (≈500 VDC), **MPPT operating range** (≈120–385 V), max input current per MPPT, number of MPPTs (2), max PV array power per MPPT.
	44	3. **EG4 6000XP battery + AC limits** — max continuous charge/discharge current to a 51.2V battery, AC continuous output (≈6 kW), AC output voltage (120/240 split-phase).
	45	4. **Docan S3 limits** — nominal voltage, usable capacity, **max continuous charge/discharge current** and **peak** per the JK BMS, recommended fuse.
	46	5. **Conductor run lengths** (one-way, feet) for voltage-drop: array→combiner, combiner→inverter (DC), inverter→battery, inverter→main/critical-loads panel. *Ask the owner — these come from the site layout.*
	47	6. **NEC code cycle adopted by the AHJ** (2020 vs 2023 NEC) — Vermont DPS. Affects 690.12 and conductor rules.
	48	7. **Site design temperatures** for `vocmax` — confirm **lat/lon** (NEK ≈ 44.5°N, −72.0°W); the library pulls NSRDB extreme-cold for the binding Voc case and 2% high for ampacity.
	49
	50	If any of 1–4 can't be confirmed from a datasheet, **state the assumption explicitly and flag it** rather than proceeding silently.
	51
	52	## 5. Validation method — NREL-grade Python is mandatory
	53	**Rule: never state a voltage, current, ampacity, string length, voltage-drop %, or kWh you did not compute by running a script.** Put scripts in `scripts/` and show your work.
	54
	55	Required computations and the library that grounds each:
	56	- **String sizing / cold-weather Voc** → `vocmax` (NEC 690.7-compliant, NSRDB extreme-temp). Confirm max modules-in-series keeps cold Voc < inverter max PV V, and Vmp(hot) stays inside the MPPT window.
	57	- **Production / per-MPPT energy sanity** → `NREL-PySAM` (Pvwattsv8, `array_type=0` fixed open-rack) or the **PVWatts V8 API** by lat/lon. *(Note: PVWatts host migrated to `developer.nlr.gov` on 2026-05-29 — verify the live host.)*
	58	- **Cross-check IV/temperature behavior** → `pvlib` (single-diode, cell-temp models) as an independent second opinion on the vocmax result.
	59	- **Conductor ampacity & voltage drop** → compute in Python from NEC 690.8 (125% × 125% continuous for PV source, temp + conduit-fill derates from NEC 310.15 tables) and standard Vdrop = 2·L·I·ρ/A. Encode the NEC ampacity tables you use; cite the table.
	60	- **Battery runtime / C-rate sanity** → simple Python: usable kWh ÷ load, and verify inverter discharge current and BMS limit aren't exceeded at 6 kW AC.
	61
	62	Each script prints its inputs, the formula/NEC section, and the result. The final design references script outputs by filename.
	63
	64	## 6. Schematic deliverables (schemdraw)
	65	Render with the `schemdraw` Python library (electrical-schematic primitives), export **both PNG and SVG**:
	66	1. **System single-line diagram (SLD)** — array → DC disconnect/combiner → inverter (PV in, battery, AC out) → critical-loads/main panel, with OCPD ratings, disconnect ratings, conductor sizes, and the 690.12 rapid-shutdown note (check 2023 Exc. 2 applicability for a non-enclosed ground-mount).
	67	2. **DC string wiring diagram** — module-level: how the ~14 panels group into strings across the two MPPTs, polarity, combiner, fusing.
	68	3. **Battery wiring diagram** — inverter ↔ Docan S3: cable gauge, Class-T fuse, battery disconnect, BMS comms link (RS485/CAN to the 6000XP).
	69
	70	Diagrams must be **internally consistent with the computed numbers** — the gauge on the drawing equals the gauge the ampacity script produced. Label every conductor and OCPD.
	71
	72	## 7. Deliverables (write these to `artifacts/`)
	73	- `electrical-design.md` — the corrected, validated electrical design narrative with every number traced to a script.
	74	- `nec-checklist.md` — Article 690 + 480/710 section-by-section pass/fail with the computed evidence.
	75	- `bom-electrical.md` — wire (gauge + length), OCPDs, disconnects, fuses, combiner, lugs, connectors — quantities from the calcs.
	76	- `sld.png` / `sld.svg`, `dc-strings.png/.svg`, `battery-wiring.png/.svg`.
	77	- `open-issues.md` — anything you couldn't validate, assumptions flagged, datasheet gaps.
	78
	79	## 8. Acceptance criteria
	80	- Cold-Voc string check passes with margin against the 6000XP max PV voltage, computed by `vocmax` (not estimated).
	81	- Hot-Vmp stays inside the MPPT operating window across the temperature range.
	82	- Every conductor has an ampacity calc (with derates) ≥ its corrected continuous current, and a voltage-drop figure ≤ 2% DC / ≤ 1% battery (or the threshold you justify).
	83	- Battery discharge at full 6 kW AC is within both inverter and BMS current limits, shown numerically.
	84	- Schematics match the calc outputs exactly.
	85	- No unverified number anywhere in the final design.
	86
	87	## 9. Working approach
	88	Confirm §4 inputs first (ask the owner the run-length and AHJ questions up front). Then optionally fan out subagents per dimension (string sizing / conductors+Vdrop / battery / NEC / schematics), each calling its grounded script, then synthesize. Adversarially double-check the string-voltage result — a cold-Voc error is a safety issue, not a typo.
	89
	90	## 10. Reference docs (read for context, in this folder's parent)
	91	- `PRSM Solar Build - Key Decisions.md` — the locked build decisions.
	92	- `PRSM Solar Build - Swarm Review.md` — prior review; note the JK BMS ↔ 6000XP RS485 comms caveat and the heated-battery/fire-code notes.
	93	- `Claude Code for Solar Design - Research.md` — the grounding-stack rationale and library details.

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	1	# Kickoff prompt — Phase 2 (paste into the fresh Claude Code session)
	2
	3	Start the session with its working directory set to this `electrical-review/` folder
	4	(so it picks up `CLAUDE.md` automatically), then paste everything below the line.
	5
	6	---
	7
	8	Read `HANDOFF-PHASE2.md` and `CLAUDE.md` in this folder first — they are the authoritative
	9	scope and task list. Then read the **Phase-1 outputs you are building on**: `artifacts/electrical-design.md`,
	10	`artifacts/open-issues.md`, `site.yaml`, `data/hardwick_usage.csv`, `artifacts/results/*.json`,
	11	and the scripts in `scripts/` (01–09, `common.py`, `nec_tables.py`). Also skim the three
	12	reference docs in the parent `prsm/` folder (Key Decisions, Swarm Review, Claude Code for Solar Design).
	13
	14	You are doing the **Phase 2 / final-state electrical design** of the PRSM off-grid solar build.
	15	**Phase 1 is already designed and validated — do not redo it; extend it.** Phase 2 wires the
	16	**remaining 17 Waaree 575W panels (full 31-panel pallet, 17.8 kW)** to meet the owner's real
	17	Hardwick Electric load (**12,237 kWh/yr, summer-peaking to 54 kWh/day**), which requires expanding
	18	the inverter (the single 6000XP's 8 kW PV input is already maxed) and the battery bank. Structure,
	19	the battery shed, and fire-code are out of scope (flag NFPA 855 as a gate, don't engineer it).
	20
	21	Before designing, confirm the inputs in HANDOFF-PHASE2 §3–§4 and **ask me these up front** (the
	22	inverter choice drives everything downstream):
	23	1. **Inverter path** — (A) parallel a 2nd EG4 6000XP (~$1,700, cheaper, two JK-BMS↔Pylontech-CAN
	24	comms) or (B) sell the 6000XP and fit a single **EG4 18kPV** (~$3,500–3,700 net, single comms;
	25	Swarm §10 recommends for >10 kW)?
	26	2. **Battery count** — 2 packs (25.7 kWh usable, Swarm §6 minimum) or 3 packs (38.6 kWh, ~1 day
	27	autonomy at average load, but crosses the NFPA 855 48-kWh threshold)?
	28	3. **Battery siting** — detached shed location (required at 3 packs) → the new inverter↔battery run length.
	29	4. **New run lengths** — array→new strings, inverter↔added battery packs, any new trench leg.
	30	If path B, also pull the **EG4 18kPV datasheet** electricals and flag anything you can't confirm.
	31
	32	Then:
	33	1. Re-string the **full 31-panel pallet** across the chosen inverter's MPPTs with
	34	`scripts/01_string_sizing.py` (+ `01b_vocmax.py`): cold-Voc ≤ 480 V design ceiling, **≤ 7 modules/series**
	35	(8S = 491 V, unsafe), hot/cold Vmp inside the MPPT window. Adversarially double-check it.
	36	2. Size **all conductors + OCPD** for the final state with `scripts/03_conductors.py` (`nec_tables.py`):
	37	12 kW AC feeder, the added PV strings (combiner?), and the battery bank — NEC 690.8 + 310.15 derates + Vdrop.
	38	3. Validate the **battery bank** with `scripts/04_battery.py`: discharge at 12 kW (~252 A) split across
	39	2–3 packs, per-pack vs bank Class-T fusing, C-rate, autonomy vs the real load (reuse `common.load_usage()`).
	40	4. Confirm **production vs load** for the full pallet (`02`/`08`/`09` — already ~20,962 kWh/yr, meets every season).
	41	5. Run the **NEC 690 + 480/705/706/710 checklist** for the final build with `scripts/05_nec_checklist.py`.
	42	6. Render the **final-state SLD + DC-string + battery-wiring** diagrams with `scripts/06_schematics.py`
	43	(extend it) → `artifacts/phase2/` (PNG + SVG), matching the computed numbers exactly.
	44
	45	Obey the CLAUDE.md rule: **no number in the final design that you didn't compute with a script.**
	46	Create a Phase-2 config (extend `site.yaml` with a `phase2:` block or add `site-phase2.yaml`; keep
	47	`site.yaml` the single source). Write all deliverables to `artifacts/phase2/` per HANDOFF-PHASE2 §7.
	48	Fan out subagents per dimension if useful, and adversarially double-check the full-pallet cold-Voc result.
	49
	50	Start by confirming scope and asking me the four questions above.
	51
	52	---

KICKOFF-PROMPT.md +39 -0

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	1	# Kickoff prompt — paste into the fresh Claude Code session
	2
	3	Start the session with its working directory set to this `electrical-review/` folder
	4	(so it picks up `CLAUDE.md` automatically), then paste:
	5
	6	---
	7
	8	Read `HANDOFF.md` and `CLAUDE.md` in this folder, plus the three reference docs in the
	9	parent `prsm/` folder (Key Decisions, Swarm Review, Claude Code for Solar Design).
	10
	11	You are doing a **narrow electrical design review** of the PRSM off-grid solar build:
	12	panel string configuration, wiring/overcurrent, inverter MPPT loading, and battery
	13	wiring — for 1× EG4 6000XP fed by ~8 kW of Waaree 575W Grade B panels, with 1× Docan S3
	14	16 kWh battery, off-grid in Northeast Vermont. Structure/mounting is already handled and
	15	is out of scope.
	16
	17	Before designing, confirm the inputs in HANDOFF §4 — pull the Waaree 575W, EG4 6000XP, and
	18	Docan S3 datasheet electricals, and **ask me** for the four conductor run-lengths and which
	19	NEC cycle (2020 vs 2023) my AHJ has adopted. Flag any spec you can't confirm.
	20
	21	Then:
	22	1. Set up the venv (`pip install -r requirements.txt`) and get an NREL API key working.
	23	2. Validate the **string configuration** with `vocmax` (cold-Voc < inverter max PV V) and
	24	cross-check with `pvlib`; confirm hot-Vmp stays in the 6000XP MPPT window.
	25	3. Size **conductors** (NEC 690.8, with 310.15 derates) and compute **voltage drop** for
	26	every run, in Python.
	27	4. Validate **battery** discharge at full 6 kW against the inverter and JK-BMS current
	28	limits; pick the Class-T fuse and cable gauge.
	29	5. Run an **NEC 690 + 480/710 checklist** with computed evidence.
	30	6. Render the **SLD + DC-string + battery-wiring** schematics with `schemdraw` (PNG + SVG),
	31	matching the computed numbers exactly.
	32
	33	Obey the CLAUDE.md rule: **no number in the final design that you didn't compute with a
	34	script.** Write all deliverables to `artifacts/`. Fan out subagents per dimension if useful,
	35	and adversarially double-check the cold-Voc string result — it's a safety constraint.
	36
	37	Start by confirming scope and asking me the run-length and NEC-cycle questions.
	38
	39	---

artifacts/README.md +22 -0

…	…	@@ -0,0 +1,22 @@
	1	# PRSM Off-Grid Solar — Electrical Deliverables Index
	2
	3	> **SELECTED BUILD = Path A (2× EG4 6000XP).** Owner decision 2026-06-03. Path B (18kPV) is retained as the documented alternative.
	4	> Every number in these deliverables is computed by a script in [`../scripts/`](../scripts/) and cited — nothing estimated (CLAUDE.md rule).
	5
	6	| Stage | System | Status | Folder | Start here |
	7	|---|---|---|---|---|
	8	| **Phase 1** | 14× 575W (8.05 kW) → 1× 6000XP → 1× Docan S3 | ✅ validated | [`./`](.) (this folder) | [electrical-design.md](electrical-design.md) |
	9	| **Phase 2 — SELECTED** | **28× 575W (16.1 kW, 4×7S) + 3 spares → 2× 6000XP (parallel) → 2× Docan S3** | 🟢 **the build** | [`phase2/`](phase2/) | [phase2/phase2-design.md](phase2/phase2-design.md) |
	10	| **Phase 2 — alternative** | 31× 575W (17.8 kW, 8+8+8+7S) → 1× EG4 18kPV → 2× Docan S3 | 📦 retained | [`phase2-pathB/`](phase2-pathB/) | [phase2-pathB/phase2-design.md](phase2-pathB/phase2-design.md) |
	11
	12	**Selected build at a glance:** 4×7S (430 V cold Voc, ≤480 V) · 8 AWG PV / 2×35→70 A AC / 2/0 battery · 4× 175 A Class-T ·
	13	126 A/pack (17% under BMS) + 126 A/inverter (14 A under 140 A) · 19,213 kWh/yr (157% of the 12,237 kWh/yr load) · ~$4,260–5,200 added (panels $0).
	14
	15	**Why Path A:** 3 spare panels (Grade-B, no warranty) + N+1 inverter redundancy + ~$1,900 cheaper + a conservative 7S string,
	16	accepting 9% less production and a battery/generator-backfilled August peak. Full A-vs-B comparison: [phase2/phase2-design.md §6](phase2/phase2-design.md).
	17
	18	**Each Phase-2 folder contains:** `phase2-design.md` · `phase2-nec-checklist.md` · `phase2-bom.md` · `phase2-open-issues.md` · `sld` / `dc-strings` / `battery-wiring` (PNG + SVG).
	19	**Computed results:** [`results/*.json`](results/) (Phase-1 `*.json`, Path B `*_phase2.json`, Path A `11_pathA.json` + `10_compare.json`).
	20	**Open gate (both paths, out of scope):** NFPA 855 / VT fire code — pre-clear with VT DPS before ordering the 2nd battery pack.
	21
	22	**Reproduce:** Path A → `python scripts/11_pathA.py && python scripts/06_schematics.py --pathA` · Path B → `python scripts/0N_*.py --phase2` · Phase 1 → `python scripts/0N_*.py` (venv: `~/.venvs/prsm-electrical`).

artifacts/battery-wiring.png +0 -0

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	1	# Electrical BOM — PRSM Off-Grid PV (Phase 1)
	2
	3	Quantities/gauges from the computed calcs (`scripts/01–04`). Lengths use the owner's
	4	run lengths (`site.yaml runs_ft`); **confirm exact trench length before buying wire.**
	5	Out of scope: racking, foundations, conduit civil, generator, propane battery heating.
	6
	7	> **Cost caveat — read this.** Unlike the gauges/ratings (which are computed and traceable),
	8	> the **Est. $ ranges are rough 2025/26 US retail estimates, not computed values.** They move
	9	> with copper prices, tariffs, and shipping, and depend on vendor/quantity. Use them for
	10	> rough planning only and confirm with live vendor quotes (Signature Solar, etc.). Pricing was
	11	> originally out of scope (CLAUDE.md); added at owner request.
	12
	13	## Conductors (copper)
	14
	15	| Use | Gauge | Type | Qty (1‑way) | Est. $ | Notes (source) |
	16	|---|---|---|---|---|---|
	17	| PV string + (×2) | **8 AWG** | PV wire/THWN‑2 90 °C | ~200 ft ×2 (~400 ft) | $250–420 | one per MPPT; ≤1.66 % Vd @250 ft (03) |
	18	| PV string − (×2) | **8 AWG** | PV wire/THWN‑2 90 °C | ~200 ft ×2 (~400 ft) | $250–420 | (03) |
	19	| PV EGC | 10 AWG | bare/green Cu | ~200 ft | $90–160 | 690.45, no source OCPD (03/05) |
	20	| Battery + and − | **2/0 AWG** (4/0 rec.) | flex welding/THW 90 °C | ~10 ft ×2 | $60–150 | **don't use the ~2 AWG cable shipped w/ pack** (03) |
	21	| Battery EGC | 6 AWG | green Cu | ~10 ft | $10–25 | 250.122 @175 A (03/05) |
	22	| AC L1/L2 | **8 AWG** | THWN‑2 | ~10 ft ×2 | $15–35 | 240.4(D): 8 AWG for 35 A breaker (03) |
	23	| AC neutral | 8 AWG | THWN‑2 | ~10 ft | $8–18 | split‑phase (03) |
	24	| AC EGC | 10 AWG | green Cu | ~10 ft | $5–12 | 250.122 @35 A (03/05) |
	25	| Array GEC | 6 AWG | bare Cu | per layout | $20–60 | to array ground rod, 690.47 (05) |
	26	| | | | **Conductors subtotal** | **$700–1,300** | dominated by ~800 ft of 8 AWG PV wire (long trench) |
	27
	28	## Overcurrent, disconnects & protection
	29
	30	| Item | Rating | Qty | Est. $ | Notes (source) |
	31	|---|---|---|---|---|
	32	| **Class‑T fuse + holder** (battery) | **175 A**, DC, 20 kAIC | 1 | $50–110 | ≥125 %×126 A, ≤2/0 ampacity (04) |
	33	| Battery DC disconnect | ≥175 A, ≥60 VDC | 1 | $40–130 | lockable, within sight of inverter (690.15/706.30) |
	34	| PV/DC disconnect (service) | ≥30 A, 600 VDC | 1 | $80–200 | load‑break at inverter (690.13); 6000XP has integral DC switch too |
	35	| AC output breaker | **35 A**, 2‑pole, 240 V | 1 | $15–45 | 40 A acceptable alt; both need 8 AWG (03) |
	36	| PV source fuses | — | **0** | $0 | not required: 1 string/MPPT, 690.9(A) Exc (03/05) |
	37	| DC + AC SPD | per Swarm §16 | 1 ea | $90–220 | exposed NEK hilltop array |
	38	| | | **OCPD/disconnect subtotal** | **$275–705** | |
	39
	40	## Inverter, battery, connectors & grounding
	41
	42	| Item | Detail | Qty | Est. $ | Notes (source) |
	43	|---|---|---|---|---|
	44	| Inverter | EG4 6000XP (locked) | 1 | **$1,500–1,650** | already decided (PRSM Key Decisions) |
	45	| Battery | Docan S3 16 kWh (base SKU; propane heat separate/out of scope) | 1 | **$1,750–2,000** | already decided |
	46	| PV connectors | MC4 (UV), 14 module pairs + crimps | set | $30–70 | (01) |
	47	| Battery lugs | 2/0–4/0 Cu ring lugs (inverter/fuse/battery studs) | ~6 | $15–45 | (03) |
	48	| BMS comms cable | RS485/CAN, JK BMS → 6000XP (Pylontech profile) | 1 | $0–30 | often included w/ battery (§3) |
	49	| Ground rod + clamp | array grounding electrode | 1 | $20–45 | 690.47 |
	50	| Labels/placards | 690.53/54/56, 110.21 (max V 430, ratings, hazards) | set | $20–60 | (05) |
	51	| | | **Connectors/grounding subtotal** | **$85–250** | (excludes the two big units above) |
	52
	53	## PV modules & freight (from prior PRSM transcripts)
	54
	55	> Panels were "already decided" / originally out of scope; pulled here from the PRSM reference
	56	> docs at owner request. Estimates, not computed.
	57
	58	| Item | Detail | Qty | Est. $ | Source |
	59	|---|---|---|---|---|
	60	| **PV modules** | Waaree 575W Bifacial Grade B — full pallet, **31 panels (17.8 kW)** | 1 pallet | **$3,284** | Key Decisions; Planning ($0.184/W, ~$106/panel) |
	61	| ↳ Phase‑1‑active allocation | **14 × 575W (~8.05 kW)** wired now; 17 = Phase‑2 inventory | — | ~$1,484 | pro‑rata of pallet |
	62	| **Freight — panel LTL** | Signature Solar → NEK terminal (FedEx Berlin / St J / Williston) via Estes/ODFL/R+L | 1 shipment | **$400–700** (~$550 verified) | Swarm §11/§13; quote freight@signaturesolar.com |
	63	| Inverter/battery parcel shipping | EG4 + Docan S3 via FedEx/UPS from SC/TX | — | often in unit price | smaller than the panel LTL; confirm at checkout |
	64
	65	Swarm §11 verified **landed ~$3,834** ($3,284 + ~$550 LTL) = **$0.215/W delivered** — still under the SolarSpace 590W alternative ($0.228/W). Grade‑B is cosmetic‑only; fine for off‑grid ground‑mount.
	66
	67	## Cost roll‑up
	68
	69	| Bucket | Est. $ |
	70	|---|---|
	71	| **PV modules** — Waaree 575W Grade B, full pallet (31 panels) | $3,284 |
	72	| **Freight** — panel LTL → NEK terminal | $400–700 |
	73	| Inverter + battery (already‑decided) | ~$3,250–3,650 |
	74	| **Electrical balance‑of‑system** (wire + OCPD + disconnects + connectors + grounding + labels) | ~$1,060–2,255 |
	75	| **Phase‑1 total — as purchased (incl. full pallet + freight)** | **~$7,995–9,890** |
	76	| *memo: Phase‑1‑active module portion only (14 of 31 panels)* | ~$1,484 of the $3,284; other 17 = Phase‑2 inventory |
	77	| *Out of scope (separate budgets):* conduit, racking, foundations, generator, trenching, propane heating | — |
	78
	79	*Notes:* (1) panel/freight figures are from the prior PRSM transcripts (Key Decisions / Swarm §11,§13 / Planning). (2) The ~$1,060–2,255 BoS aligns with the Swarm §13 BoS line ($1,920–2,290), which also folded in conduit (civil/out of scope here). (3) This ~$8–9.9K is the **electrical + modules** slice only; the full Phase‑1 build (with structure, generator, conduit, permits) runs **~$17–22K per Swarm §13.**
	80
	81	## String / array summary (from `01`)
	82
	83	- **14× Waaree 575W**, configured **2 strings of 7 series (7S×1P)**, one per MPPT.
	84	- String cold Voc **430 V** (≤480 V design ceiling); string Imp 13.1 A; per‑MPPT 4025 W.
	85	- **Hard rule: 7 modules per string maximum** (8S = 491 V, unsafe). Surplus pallet panels are Phase‑2 inventory.
	86
	87	> Gauges, the 175 A fuse, and every electrical rating here were computed in `scripts/` and match the schematics in `artifacts/`. **The $ figures are estimates only** (see cost caveat above).

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	1	# PRSM Off-Grid Solar — Validated Electrical Design
	2
	3	**Scope:** DC array string config, wiring/OCPD, inverter MPPT loading, battery wiring,
	4	grounding/labeling at SLD level. Structure/mounting out of scope.
	5	**System:** 14× Waaree 575W → 1× EG4 6000XP → 1× Docan S3 16 kWh · off-grid · NE Vermont (NEK) · **NEC 2023**.
	6	**Date:** 2026-06-02 · **Code discipline:** every load-bearing number below was computed by a script in `scripts/` and is cited by filename. Nothing is estimated.
	7
	8	> Reproduce: `~/.venvs/prsm-electrical/bin/python scripts/0N_*.py`. Computed outputs are in `artifacts/results/*.json`. The venv lives outside this Google-Drive folder (so Drive doesn't sync ~thousands of package files); rebuild with `python3.13 -m venv ~/.venvs/prsm-electrical && pip install -r requirements.txt` (then `vocmax` via `--no-deps`).
	9
	10	---
	11
	12	## 0. Confirmed datasheet inputs (the basis for everything)
	13
	14	| Component | Key electricals (source) |
	15	|---|---|
	16	| **Waaree Elite BiN‑08‑575** (144‑HC N‑TOPCon bifacial, Grade B "BIN‑08‑575B") | Voc **52.30 V**, Vmp **43.86 V**, Isc **13.87 A**, Imp **13.11 A**, β(Voc) **−0.26 %/°C**, γ(Pmax) −0.30 %/°C, α(Isc) +0.046 %/°C, max system **1500 V**, 30 A series fuse. *Waaree USA datasheet; cross‑checked Missouri W&S / A1SolarStore.* |
	17	| **EG4 6000XP** | PV: 2 MPPT, **500 V abs max** / **480 V design ceiling** / **120–385 V MPPT track**, **17 A/MPPT** input, 25 A Isc/MPPT, **8000 W** (4000/MPPT; 10 kW oversize cap). Batt 46.4–60 V, **125 A charge / 140 A discharge**, eff 93%. AC **6000 W / 12 kW surge**, 120/240 split, 25 A/leg, 50 A pass‑through. Integrated DC disconnect, **RSD initiator, PV AFCI, GFDI**. *EG4 Manual + Spec Sheet v1.4.4.* |
	18	| **Docan S3** | 51.2 V, 58.4 V charge, **314 Ah / 16.08 kWh**, 16S1P EVE MB31. JK‑PB2A16S20P BMS: **150 A discharge OCP (300 s)**, 200 A marketed, 300 A short‑circuit (20 µs), **cell‑honest ~157 A (0.5P)**, −20 °C low‑temp charge cutoff. *Docan listing + JK BMS datasheet + EVE MB31 cell datasheet.* |
	19
	20	**Two datasheet findings that changed the design:**
	21	1. The EG4 "480 vs 500" numbers are **both real**: 500 V = absolute do‑not‑exceed (warranty void), 480 V = recommended DC‑input ceiling, 385 V = MPPT *tracking* max (not a Voc limit). Cold‑Voc is sized to **≤480 V** with 500 V as the hard backstop.
	22	2. The Waaree is the **144‑cell BiN‑08 (Voc 52.30 V)**, not the look‑alike 108‑cell BiN‑01 (Voc 39.91 V). Using the wrong SKU would corrupt the cold‑Voc check.
	23
	24	---
	25
	26	## 1. PV string configuration — the binding safety constraint · `scripts/01_string_sizing.py`
	27
	28	**Result: 2 strings of 7 modules in series (7S × 1P), one string per MPPT, 14 modules, 8050 W DC.**
	29
	30	Cold‑weather open‑circuit voltage (NEC 690.7), at the **−40 °C** regional design low (upgraded from −34 °C on adversarial review — Bloomfield VT has recorded −45.6 °C), **including a bifacial rear‑gain Voc adder**:
	31
	32	| Quantity | Value | Check |
	33	|---|---|---|
	34	| Voc per module, −40 °C (temp only) | **61.14 V** | analytic 690.7 linear |
	35	| Voc per module, pvlib CEC single‑diode | **61.26 V** | independent — agrees to **0.12 V** |
	36	| Bifacial rear‑gain adder | +0.30 V | rear 0.20 × bifaciality 0.80 |
	37	| **Voc per module used (cold + bifacial)** | **61.44 V** | binding value |
	38	| **7S string cold Voc** | **430.1 V** | **≤ 480 V design (PASS, 49.9 V margin)** · ≤ 500 V abs (69.9 V) |
	39	| 8S string cold Voc | 491.5 V | **FAILS 480 V (−11.5 V); only 8.5 V under 500 V → do not build** |
	40
	41	**MPPT operating window (120–385 V):**
	42	- Cold Vmp (−40 °C): **376.1 V** (analytic) / 374.6 V (pvlib) — under the 385 V tracking max by ~9 V. *Expected behavior:* on the coldest clear mornings the inverter may briefly clamp the operating point at 385 V (a few % harvest, not a fault).
	43	- Hot Vmp (70 °C cell): **259.2 V** — well above the 120 V floor. **PASS.**
	44
	45	**Per‑MPPT loading:** string 4025 W vs 4000 W usable (within the 5000 W/MPPT oversize allowance — ~25 W clip only at rare full‑STC peaks); Imp 13.11 A ≤ 17 A input; Isc 13.87 A ≤ 25 A rating. Array DC:AC = 1.34 (winter‑favorable). **PASS.**
	46
	47	**Quadruple‑validated (a cold‑Voc error is a safety issue, not a typo):**
	48	1. Analytic NEC 690.7 linear correction — `01_string_sizing.py` → module Voc 61.14 V.
	49	2. pvlib CEC six‑parameter single‑diode (`fit_cec_sam`, PySAM solver) → module Voc **61.26 V** (agrees to 0.12 V).
	50	3. **vocmax** — the named NEC‑690.7 grounding tool — `01b_vocmax.py` in a pinned venv (`~/.venvs/prsm-vocmax`, py3.9 + pvlib 0.9.5) → module Voc **61.14 V** @ −40 °C, 7S = 428 V, **max 7 modules/series ≤ 480 V** (8S = 8th would exceed). *(vocmax's NSRDB statistical worst‑case needs an NREL key — open item; the offline full‑sun run reproduces the linear 690.7 form exactly.)*
	51	4. **Independent adversarial re‑derivation** (separate agent, keyed the datasheet fresh): *"7S is CONFIRMED SAFE and is the correct maximum; 8S must not be built."* It also verified the bifacial gain and the −40 °C assumption strengthen, not weaken, the result.
	52
	53	All four agree: module Voc ≈ **61.1–61.3 V** at −40 °C → 7S ≈ **428–430 V** (≤ 480 V), 8S = **491 V** (fails). vocmax 1.0.4 is incompatible with the main env's pvlib 0.15 (it imports the removed `get_psm3`), hence the separate pinned venv.
	54
	55	> **Carry‑forward note for the SLD/labels:** the array max is **7 modules/string**. Surplus pallet panels are Phase‑2 inventory — do **not** extend a string to 8S (491 V).
	56
	57	---
	58
	59	## 2. Conductors, voltage drop & overcurrent · `scripts/03_conductors.py`
	60
	61	NEC 690.8 design current + 310.15(B)/(C) derates + 240.4(D) + Chapter 9 Table 8 voltage drop. Tables encoded and cited in `scripts/nec_tables.py`.
	62
	63	| Run | Cont. current | Gauge (Cu) | Driver | Ampacity basis | Vdrop | OCPD | EGC |
	64	|---|---|---|---|---|---|---|---|
	65	| **PV string** array→inv (×2, one/MPPT) | Imp 13.11 A | **8 AWG** | voltage‑drop | Isc×1.25×1.25 = 21.7 A term; 17.3 A after 0.91×0.80 derate (8 AWG = 25 A@75 °C) | **1.33 %** @200 ft (0.99/1.33/1.66 % at 150/200/250 ft) | **none req.** (690.9(A) Exc — 1 string/MPPT) | 10 AWG |
	66	| **Battery** ↔ inverter | 126.0 A | **2/0 AWG** | ampacity | 125%×126 = 157.5 A (2/0 = 175 A@75 °C) | **0.48 %** | **175 A Class‑T** | 6 AWG |
	67	| **AC output** inv→main panel | 25.0 A | **8 AWG** | 240.4(D) | 125%×25 = 31.25 A (10 AWG meets ampacity but 35 A breaker > 10 AWG's 30 A cap → 8 AWG) | **0.16 %** | **35 A 2‑pole** | 10 AWG |
	68
	69	- **PV string is voltage‑drop‑driven, not ampacity‑driven:** 8 AWG holds ≤2 % across your entire stated 150–250 ft range (worst case 1.66 % @250 ft). The ampacity minimum is only 12 AWG; 8 AWG is chosen for the long trench run. Conductors are 90 °C THWN‑2/PV wire in Schedule‑40 PVC conduit (rodent/UV per Swarm §16); ambient modeled at a conservative 40 °C with 4 current‑carrying conductors (both strings in one conduit).
	70	- **Battery cable: do not use the 35 mm² (~2 AWG) cable that may ship with the pack** — 2 AWG (115 A@75 °C) is below the 157.5 A continuous requirement. Use **2/0 minimum**; **4/0 recommended** (Vdrop 0.30 %, margin + low loss).
	71	- **AC OCPD:** 35 A 2‑pole is the code minimum (≥125 %×25 A); 40 A is the common alternative — both require 8 AWG.
	72
	73	---
	74
	75	## 3. Battery discharge, C‑rate & Class‑T fuse · `scripts/04_battery.py`
	76
	77	At full 6 kW AC, battery discharge = **126.0 A** (6000 W ÷ 0.93 ÷ 51.2 V). It clears **every** limit:
	78
	79	| Limit | Value | Margin |
	80	|---|---|---|
	81	| Inverter max discharge (**binding**) | 140 A | **+14 A (10 %)** |
	82	| JK‑BMS discharge OCP (300 s) | 150 A | +24 A |
	83	| EVE cell‑honest 0.5P | 157 A | +31 A |
	84	| JK‑BMS marketed max | 200 A | +74 A |
	85
	86	- **C‑rate:** 0.40C discharge, 0.40C charge (PV 125 A) — both ≤ 0.5C. **PASS.**
	87	- **Surge:** a 12 kW/3.5 s inverter surge pulls ~252 A — above the 200 A marketed and 157 A cell figures but **below the 300 A short‑circuit trip and far too brief to trip the 150 A/300 s OCP**; a 175 A Class‑T at 1.44× will not nuisance‑open. *One pack cannot sustain >6 kW continuously — Phase‑2 second pack adds surge headroom.*
	88	- **Runtime (sanity):** 2.68 h at full 6 kW (2.14 h at 80 % DoD); 8.6 h at a 1.5 kW average load (80 % DoD). **NEK winter still requires the generator** (Swarm §2) — see §4.
	89	- **Class‑T fuse: 175 A, DC‑rated, 20 kAIC.** ≥ 125 %×126 A = 157.5 A; ≤ 2/0 cable ampacity (175 A); interrupt rating covers the LFP pack's prospective fault current. **Layered protection:** BMS protects cells (150 A/300 s, 300 A SC), the fuse protects the cable + provides fault‑current interruption.
	90	- **Cold‑weather charging — heating CONFIRMED (owner), propane‑based.** The battery is kept warm by **propane heat on a separate budget**, bringing the cells into the ≥ 0 °C charge window so the pack **charges through NEK winter**. (The EVE MB31 cell only charges ≥ 0 °C; the −20 °C BMS cutoff alone would not protect it.) Because it's propane, it places **no parasitic electrical load** on the array/battery — a net positive for December's scarce ~15.7 kWh/day (§4). The heating itself is out of electrical scope (like structure/mounting); the only electrical‑side check is that the BMS gates charge on cell temperature (`open-issues.md` item 13).
	91
	92	---
	93
	94	## 4. Production sanity (off‑grid worst‑month) · `scripts/02_production.py`
	95
	96	PVWatts v8, 8.05 kW, fixed open rack (array_type 0), tilt 50°, az 180°, 14 % losses.
	97	**Host note:** the canonical `developer.nrel.gov` did **not** respond; the script verified and used **`developer.nlr.gov`** — confirming the 2026‑05‑29 migration noted in the project docs (tested, not assumed).
	98
	99	| | kWh/day | |
	100	|---|---|---|
	101	| Annual | 9,622 kWh/yr (CF 13.6 %) | |
	102	| **December (binding)** | **15.7** | the off‑grid worst case |
	103	| January | 24.3 | |
	104	| June | 27.7 | winter:summer = **0.57** |
	105
	106	This quantifies the NEK winter‑starvation argument: a 16 kWh pack at 80 % DoD = ~12.9 kWh, and December produces ~15.7 kWh/day **before** multi‑day cloudy stretches. The **backup generator (Phase 1)** and **Phase‑2 PV expansion** (Swarm §2, §6) are confirmed necessary, not optional. *(Run with your own NREL key for site‑exact lat/lon; DEMO_KEY was used here.)*
	107
	108	---
	109
	110	## 5. Grounding, bonding & labeling (SLD level) · `scripts/05_nec_checklist.py`
	111
	112	- **Equipment grounding conductors (250.122):** PV 10 AWG, **battery 6 AWG** (175 A OCPD), AC 10 AWG. Bond all array frames + enclosures (690.43).
	113	- **Array grounding electrode (690.47):** drive a ground rod at the array; **6 AWG Cu GEC**, common with the dwelling grounding electrode system. *(ACTION)*
	114	- **DC ground‑fault / arc‑fault (690.11/690.41):** provided integral to the 6000XP (PV AFCI + GFDI/isolation).
	115	- **Labels & placards (690.53/54/56, 110.21):** max system voltage (430 V), inverter output rating, DC disconnect + directory, battery hazard label, RSD placard if the AHJ requires it. *(ACTION)*
	116
	117	Full section‑by‑section pass/fail with computed evidence: **`artifacts/nec-checklist.md`** (16 PASS, 1 verify‑with‑AHJ, 2 action items, 1 N/A).
	118
	119	---
	120
	121	## 6. Schematics · `scripts/06_schematics.py` → `artifacts/`
	122
	123	Rendered from the result JSONs so the gauges/ratings on the drawings equal the calc outputs:
	124	- **`sld.{png,svg}`** — array → DC disconnect → 6000XP (PV/batt/AC) → subfed main panel, with all OCPD/disconnect/conductor ratings + GEC.
	125	- **`dc-strings.{png,svg}`** — 2×7S across MPPT1/MPPT2, polarity, "no source fuse" + "max 7/string" notes.
	126	- **`battery-wiring.{png,svg}`** — 6000XP ↔ Docan S3: 2/0 cable, 175 A Class‑T, disconnect, JK‑BMS → Pylontech‑CAN comms link.
	127
	128	---
	129
	130	## Bottom line
	131
	132	The configuration is electrically sound and code‑compliant for off‑grid NEC 2023: **7S×2 strings** (430 V cold Voc, 50 V under the design ceiling), **8 AWG PV / 2/0 battery / 8 AWG AC** conductors all within ampacity and voltage‑drop targets, **175 A Class‑T** battery fuse, and battery discharge comfortably inside every current limit at 6 kW. Open items (run‑length measurement, AHJ rapid‑shutdown stance, BMS closed‑loop comms, NREL key for vocmax/NSRDB) are in **`artifacts/open-issues.md`** — none change the validated design.

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	1	# NEC Article 690 + 480/706/710 Checklist — PRSM Off-Grid PV
	2
	3	**Code cycle:** NEC **2023** (VT DPS Division of Fire Safety, per owner). Off-grid stand-alone.
	4	**Evidence is computed** by `scripts/01–05` and pulled from `artifacts/results/*.json` (re-run `scripts/05_nec_checklist.py`). Summary: **16 PASS · 1 verify‑with‑AHJ · 2 action · 1 N/A.**
	5
	6	| § | Topic | Status | Computed evidence |
	7	|---|---|---|---|
	8	| **690.7** | Max system voltage (cold Voc) | ✅ PASS | 7S cold Voc **430.1 V** ≤ 480 V design / 500 V abs (margin 69.9 V). Tmin −40 °C; analytic + pvlib agree to 0.12 V; adversarially re‑derived. |
	9	| **690.8(A)** | Max circuit current (Isc×1.25) | ✅ PASS | PV source max current **17.3 A** (Isc 13.87 × 1.25). |
	10	| **690.8(B)** | Conductor ampacity after 310.15 derates | ✅ PASS | PV string **8 AWG Cu**: 25 A@75 °C; derated 21.8 A (×0.91 temp ×0.80 fill) ≥ req 17.3 A. |
	11	| **690.9 / (A) Exc** | PV source overcurrent (string fusing) | ✅ PASS | **Not required** — 1 string per MPPT (no parallel strings); no source fault current can exceed the 30 A module series‑fuse rating. Each MPPT isolated. |
	12	| **690.9 / 240 / 480.9** | Battery overcurrent (Class‑T) | ✅ PASS | **175 A Class‑T** (DC, 20 kAIC) ≥ 125 %×126.0 A; ≤ 2/0 cable ampacity 175 A. |
	13	| **690.9 / 710.15** | Inverter AC output overcurrent | ✅ PASS | **35 A 2‑pole** ≥ 125 %×25.0 A; protects 8 AWG Cu (240.4(D)). |
	14	| **690.12** | Rapid shutdown | ⚠️ **VERIFY‑AHJ** | Ground‑mounted array **not on a building** — 690.12 (2023) applies to PV on/in buildings. The 6000XP has a built‑in RSD initiator if the AHJ requires it for conductors entering the dwelling. **Confirm AHJ stance for the detached ground‑mount.** |
	15	| **690.13** | PV disconnecting means | ✅ PASS | 6000XP integrated DC switch per MPPT; add an external load‑break PV/DC disconnect at the inverter for service isolation. |
	16	| **690.15** | Disconnect for equipment | ✅ PASS | Battery disconnect (or the fused Class‑T disconnect) within sight of the inverter. |
	17	| **690.11 / 690.41** | DC arc‑fault + system grounding (GFDI) | ✅ PASS | 6000XP integrated PV AFCI (690.11) and PV ground‑fault / isolation (690.41/690.5). |
	18	| **690.43** | Equipment grounding & bonding | ✅ PASS | EGCs: PV 10 / **battery 6** / AC 10 AWG Cu; bond array frames + all enclosures. |
	19	| **690.45** | Size of EGC (250.122) | ✅ PASS | Battery EGC **6 AWG** (175 A OCPD); AC EGC 10 AWG (35 A); PV EGC min 10 AWG (no source OCPD). |
	20	| **690.47** | Grounding electrode (array + DC) | 🔧 **ACTION** | Drive an array grounding electrode (rod) and bond per 690.47(A); min **6 AWG Cu GEC**, common with the dwelling GES. |
	21	| **690.31** | Wiring methods | ✅ PASS | PV in Schedule‑40 PVC conduit (rodent/UV, Swarm §16); **8 AWG Cu** PV wire/THWN‑2 90 °C. |
	22	| **706.30 / 480.7** | ESS disconnecting means | ✅ PASS | Lockable battery disconnect + Class‑T fuse within sight of the ESS. |
	23	| **706.31 / 480.9** | ESS overcurrent protection | ✅ PASS | **175 A Class‑T** at battery positive; 20 kAIC > pack prospective fault current. |
	24	| **710.15** | Stand‑alone system output | ✅ PASS | 6000XP 6 kW 120/240 split‑phase; output 25.0 A; no utility backfeed (off‑grid). |
	25	| **705** | Interconnection (120 % / backfeed) | ➖ N/A | Off‑grid, no utility interconnection. Main panel **subfed with main breaker locked off** (Swarm §17). |
	26	| **690.53/54/56 · 110.21** | Labels & placards | 🔧 **ACTION** | Generate per computed ratings: max system voltage (430 V), inverter output rating, DC disconnect + directory, battery hazard label, RSD placard *if* AHJ requires it. |
	27	| Voltage drop (design target) | DC ≤2 % / batt ≤1 % / AC ≤2 % | ✅ PASS | DC **1.33 %** (0.99/1.33/1.66 % at 150/200/250 ft); battery **0.48 %**; AC **0.16 %**. (Informational — not NEC‑mandated.) |
	28
	29	## The 3 items that need owner / AHJ action
	30
	31	1. **690.12 rapid shutdown (VERIFY‑AHJ).** As a detached ground‑mount the array is most likely *exempt* (690.12 governs PV on buildings), but the conductors enter the dwelling. Get the VT DPS inspector's position in writing. The 6000XP can provide the RSD initiator if required (external E‑stop + any module‑level transmitter are **not** included).
	32	2. **690.47 array grounding electrode (ACTION).** Install a ground rod at the array, 6 AWG Cu GEC, bonded to the dwelling grounding electrode system.
	33	3. **Labeling (ACTION).** Produce the 690.53/54/56 placards from the computed ratings before inspection.
	34
	35	All other Article 690/480/706/710 requirements pass with computed evidence above.

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	1	# Open Issues, Assumptions & Datasheet Gaps — PRSM Electrical Review
	2
	3	Nothing here changes the validated design (§ refer to `electrical-design.md`); these are
	4	items to confirm/measure, flagged assumptions, and where I substituted a defensible value.
	5
	6	## A. Confirm before buying wire / energizing
	7
	8	1. **Exact conductor run lengths.** You gave ranges; the design used the conservative/representative value and proved robustness:
	9	- DC array→inverter: **designed at 200 ft; 8 AWG holds ≤2 % across your full 150–250 ft range** (0.99 %/1.33 %/1.66 %). Measure the actual trench length for wire *quantity*; the *gauge* won't change.
	10	- Battery 5–10 ft → used 10 ft; AC <10 ft → used 10 ft. Both short; gauge insensitive within the range.
	11	2. **690.12 rapid shutdown — AHJ stance (VERIFY‑AHJ).** A detached ground‑mount is most likely exempt (690.12 governs PV on buildings), but conductors enter the dwelling. **Get the VT DPS inspector's position in writing.** The 6000XP supplies the RSD initiator if required; the external E‑stop and any module‑level transmitter are **not** included.
	12	3. **Array grounding electrode (690.47, ACTION).** Drive a ground rod at the array; 6 AWG Cu GEC bonded to the dwelling GES.
	13	4. **Labels/placards (690.53/54/56, ACTION).** Produce from the computed ratings (max system V = 430 V, output rating, disconnects, battery hazard) before inspection.
	14	5. **AC subfeed topology (Swarm §17).** Plan is to feed the existing main panel as a subpanel with its main breaker locked off — confirm the panel supports this (main lockable, busbar/feed arrangement) and that 35 A 2‑pole output OCPD + 8 AWG matches the panel's input lugs.
	15
	16	## B. Inputs I substituted with a defensible value (no datasheet/owner confirmation yet)
	17
	18	6. **NREL API key — not provided.** Consequences and mitigations:
	19	- **Cold‑Voc (safety):** used the documented **−40 °C** NEK record‑class low. This is *colder* than the NSRDB extreme would likely return, so the result is conservative and an NSRDB pull would only *loosen* it. The script auto‑uses `min(documented, NSRDB)` once a key is set.
	20	- **Production:** ran on `DEMO_KEY`. Rerun `02_production.py` with your key for site‑exact numbers.
	21	- **vocmax NSRDB statistical worst‑case (P99.5):** not run — the offline vocmax run (`01b_vocmax.py`) reproduces the linear 690.7 result (428 V) but not the NSRDB statistics. **To enable:** `export NREL_API_KEY=… NREL_EMAIL=…` (free at developer.nrel.gov).
	22	- **API host:** verified empirically — `developer.nrel.gov` did **not** respond; `developer.nlr.gov` did (the 2026‑05‑29 migration in the project docs is real here). `02_production.py` tries both.
	23	7. **Exact site lat/lon.** Used 44.5, −72.0 (approx NEK). Confirm for site‑exact production; immaterial to the −40 °C cold‑Voc.
	24	8. **Tilt 50° / azimuth 180°.** Assumed winter‑optimized true‑south; affects production only — confirm.
	25	9. **Bifacial rear‑irradiance fraction.** Used **0.20** (× 0.80 bifaciality) for the cold‑Voc adder (+0.30 V/module). Conservative for a ground‑mount; 7S passes with margin even well above this. Winter snow albedo can raise rear irradiance, but winter is the cold case already bounded.
	26	10. **Conductor thermal environment.** PV modeled at 40 °C ambient with 4 current‑carrying conductors in one conduit (conservative). Separate conduits or cooler buried runs add margin. PV gauge is voltage‑drop‑driven, so ampacity assumptions aren't binding.
	27
	28	## C. Datasheet gaps / vendor caveats (from the research agents)
	29
	30	11. **Docan "200 A" BMS rating is soft.** The EVE MB31 cell's honest continuous limit is ~**157 A** and the JK BMS trips discharge at **150 A/300 s**; "200 A" is a short‑term MOSFET figure. Design used the cell‑honest reality. At 6 kW you draw **126 A** — ample margin. **One pack cannot sustain >6 kW continuously**; the 12 kW/3.5 s surge (252 A) is a safe transient. Phase‑2 second pack adds headroom.
	31	12. **JK BMS ↔ 6000XP closed‑loop comms (Swarm §9).** Pylontech‑CAN profile, 6000XP "Pylontech 2", JK **V19** firmware. Not plug‑and‑play (budget config time). **Open‑loop fallback is fully viable** (no battery‑life penalty). Verify firmware on arrival.
	32	13. **Battery heating — ✅ CONFIRMED: propane‑based, separate (non‑electrical) budget.** Retires the cold‑charge risk (EVE cell charges only ≥ 0 °C; the −20 °C BMS cutoff alone wouldn't protect it) and, being propane, places **no parasitic electrical load** on the array/battery. Out of electrical scope, like structure/mounting. Only electrical‑side check: confirm the **BMS gates charge on cell temperature** so it permits charge only once cells reach ≥ 0 °C (standard for these JK packs). *(If a propane control/blower happens to draw from this electrical system, tell me and I'll add it as a winter load — but "separate budget" implies it's independent.)* **Out‑of‑scope safety pointer:** a propane appliance in/near a Li‑battery enclosure needs combustion‑air, ventilation, and fire‑separation handling — keep that in the enclosure & fire‑code review (Swarm §4, NFPA 855), not here.
	33	14. **No vendor‑published battery fuse/cable spec.** The 175 A Class‑T and 2/0 cable are **engineer‑selected** (computed in `03`/`04`), not vendor values. The ~2 AWG cable that may ship with the pack is **undersized** for 6 kW — use 2/0 (4/0 recommended).
	34	15. **Verify the module at receiving.** Confirm the physical Waaree label/datasheet is **BiN‑08‑575 (Voc 52.30 V, 144‑cell)** — Signature Solar could substitute a batch; a different SKU (e.g., 108‑cell BiN‑01 at 39.91 V) would change string sizing.
	35
	36	## D. Adjacent items (noted, not in this electrical scope)
	37
	38	16. **Backup generator (Phase 1, Swarm §2).** AC‑IN to the 6000XP (50 A pass‑through) for generator‑assist charging on low SOC; wire the L14‑30 inlet + interlock per that path.
	39	17. **Phase‑2 PV expansion** with surplus pallet panels (Swarm §6) directly attacks the winter‑starvation shown in `02` (Dec 15.7 kWh/day). **Keep each string at 7 modules max** (8S = 491 V, unsafe) when expanding.
	40	18. **Insurance / NFPA 855 / permitting** — covered in the PRSM Swarm Review; out of electrical‑review scope.
	41
	42	## E. Validation status of the safety‑critical result
	43
	44	The cold‑Voc string result (7S, 430 V ≤ 480 V) is confirmed by **four independent methods**: analytic NEC 690.7, pvlib CEC single‑diode, **vocmax** (the named tool, offline), and an independent adversarial agent. The only vocmax capability not exercised is its NSRDB statistical worst‑case, which needs the NREL key (item 6) and would only relax the already‑conservative −40 °C result.

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	1	# Phase 2 — Electrical Bill of Materials (added equipment, final state)
	2
	3	**Quantities are computed** (string layout `01`, conductors `03`, battery `04`); **dollar figures are ESTIMATES**
	4	(sourced from Swarm §10 / Key Decisions / `09_phase2.py`), clearly labeled as such. The remaining **panels are $0**
	5	(already owned — sunk in the pallet). Structure / shed / racking / trenching civil are **out of scope**.
	6
	7	Owner's chosen final state (2026-06-03): **sell the 6000XP → 1× EG4 18kPV**, **+1 Docan S3 (→ 2 total)**, battery adjacent,
	8	17 remaining panels co-located on the reused 200 ft trench.
	9
	10	## Major equipment
	11
	12	| Item | Qty | Computed basis | Cost (estimate) | Source |
	13	|---|---|---|---|---|
	14	| **EG4 18kPV-12LV** hybrid inverter | 1 | 12 kW AC / 18 kW PV / 3 MPPT hosts all 31 panels (`01`) | **$4,500** retail | Swarm §10 |
	15	| — less **EG4 6000XP** resale (sold) | −1 | replaced; strong secondary market | **−$800 to −1,000** | Swarm §10 |
	16	| **EG4 18kPV net** | | | **≈ $3,500 – 3,700** | |
	17	| **Docan S3 16 kWh** pack (added) | +1 (→ 2 total) | 2 packs = 25.7 kWh usable; 124.7 A/pack ≤ 150 A BMS (`04`) | **$1,758 – 2,000** | Key Decisions |
	18	| **Waaree 575W** panels (remaining) | 17 (→ 31 total) | full pallet 17.8 kW (`01`/`09`) | **$0** (owned) | — |
	19
	20	## Balance of system (computed gauges/ratings; estimated $)
	21
	22	| Item | Qty / spec | Computed basis (`03`/`04`) | Notes |
	23	|---|---|---|---|
	24	| PV wire **8 AWG** THWN-2 / PV (90 °C) | ~1,600 ft (4 strings × 2 × 200 ft) | Vdrop-driven, 1.33 % @ 200 ft, 8 CCC | reuse Phase-1's ~800 ft (2 strings) + ~800 ft new |
	25	| PV EGC **10 AWG** | ~200 ft+ | 690.45 (no source OCPD) | — |
	26	| AC feeder **4 AWG** Cu + **8 AWG** EGC | ~10 ft ×2 + EGC | 50 A × 125 % → 70 A; 240.4(D) | upsize from Phase-1's 8 AWG |
	27	| **70 A 2-pole** breaker (AC output) | 1 | ≥ 125 % × 50 A (`03`) | replaces Phase-1's 35 A |
	28	| Battery **2/0** Cu (per-pack) + **6 AWG** EGC | 2 packs × ~5 ft ×2 | 124.7 A/pack, 175 A Class-T (`04`) | 1 set reused from Phase 1 |
	29	| Battery bank cable **2× 4/0** (or 400 kcmil / 2×2/0) per polarity | ~10 ft × 4 (2 parallel ×2) | 249 A, ≥ 312.5 A ampacity (`03`) | 2×4/0 = 460 A, low-loss, flexible |
	30	| **DC busbar, 250 A** (e.g. Lynx-style, + / −) | 1 | bank busing point for 2 packs (`03`/`04`) | — |
	31	| **175 A Class-T** fuse + holder (DC, 20 kAIC) | 2 (1 added) | per-pack primary OCP (`04`) | 1 reused from Phase 1 |
	32	| **Bank disconnect, 250 A DC** (lockable) | 1 | 690.15 / 706.30 / 480.7 | — |
	33	| Per-pack disconnects | 2 | 706.30 | — |
	34	| External DC/PV disconnect (load-break) | 1 | 690.13 service isolation (18kPV has integral) | — |
	35	| 2nd PV conduit (Sched-40 PVC) run | ~200 ft | split 8 CCC → 2 conduits (`03`/`05`) | squirrel/UV (Swarm §16) |
	36	| Lugs, MC4, labels/placards (690.53/54/56) | set | from computed ratings | ACTION item |
	37	| **No combiner box** | 0 | 18kPV takes strings direct (`01`, datasheet) | — |
	38
	39	## Cost roll-up (ESTIMATE — not computed; energy/sizing above ARE computed)
	40
	41	| Bundle line | Estimate |
	42	|---|---|
	43	| EG4 18kPV (net of 6000XP resale) | $3,500 – 3,700 |
	44	| +1 Docan S3 pack | $1,758 – 2,000 |
	45	| Remaining 17 Waaree panels | $0 (owned) |
	46	| BoS (PV/AC/battery wire, busbar, Class-T, 70 A breaker, bank disconnect, conduit, lugs, labels) | $800 – 1,500 |
	47	| **Total added (Phase 2, owner's chosen config)** | **≈ $6,060 – 7,200** |
	48
	49	*This sits between `09_phase2.py`'s pre-baked "lean" and "recommended" bundles because the chosen config is the 18kPV (not a
	50	parallel 6000XP) with **only one added pack** (2 total, not 3). Excludes structure/shed/fire-code (out of scope) and the generator
	51	(Phase-1 infrastructure).*

artifacts/phase2-pathB/phase2-design.md +190 -0

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	1	# PRSM Off-Grid Solar — Phase 2 / Path B (1× EG4 18kPV) — RETAINED ALTERNATIVE
	2
	3	> **STATUS — RETAINED ALTERNATIVE (not the selected build).** The owner selected **Path A (2× EG4 6000XP)** on 2026-06-03;
	4	> the build follows [`../phase2/`](../phase2/phase2-design.md). This Path-B (18kPV) design is fully validated and kept on file
	5	> as the documented alternative. Where the text below says "final"/"chosen", read it as "the Path-B design" — Path A is the build.
	6
	7	**Scope:** Final full-build electrical state — re-string the full 31-panel pallet, expand the inverter,
	8	expand the battery bank, re-validate every conductor/OCPD, render the final-state diagrams. Structure,
	9	the battery shed, NFPA 855 fire code, and pricing-beyond-estimate are **out of scope (flagged, not engineered)**.
	10	**System (final):** 31× Waaree 575W (17.8 kW DC) → **1× EG4 18kPV-12LV** (12 kW AC / 18 kW PV, 3 MPPT) →
	11	**2× Docan S3** (25.7 kWh usable) → subfed main panel + generator AC-IN · off-grid · NE Vermont (NEK) · **NEC 2023**.
	12	**Date:** 2026-06-03 · **Builds on the validated Phase-1 design** (`artifacts/electrical-design.md`) — extends it, does not redo it.
	13
	14	> **Code discipline (CLAUDE.md):** every load-bearing number below was computed by a script in `scripts/` (run with `--phase2`)
	15	> and is cited by filename. Nothing is estimated. Reproduce: `~/.venvs/prsm-electrical/bin/python scripts/0N_*.py --phase2`.
	16	> Computed outputs live in `artifacts/results/*_phase2.json`. The Phase-2 config is the `phase2:` block in `site.yaml`
	17	> (deep-merged over the base by `common.load_site(phase2=True)`), so `site.yaml` stays the single source and Phase-1 still reproduces.
	18
	19	---
	20
	21	## 0. Owner decisions (confirmed 2026-06-03) + the inverter that changed the rules
	22
	23	| Decision | Choice | Driver |
	24	|---|---|---|
	25	| **Inverter path** | **B — sell the 6000XP, fit one EG4 18kPV** | Swarm §10 (>10 kW); only path that hosts all 31 panels |
	26	| **Battery count** | **2× Docan S3** (25.7 kWh usable) | Swarm §6 minimum; generator covers deep autonomy |
	27	| **Battery siting** | Adjacent to inverter (~10 ft, as Phase 1) | best Vdrop at the 250 A bank current |
	28	| **New PV runs** | 17 remaining panels co-located w/ Phase-1 array; reuse the 200 ft trench | no new trench leg |
	29
	30	**The single most important Phase-2 finding:** the Phase-1 "**≤ 7S / ≤ 480 V**" rule was *specific to the 6000XP's*
	31	480 V design / 500 V absolute ceiling. The **EG4 18kPV raises the ceiling to 550 V (MPPT high-voltage fault protection) /
	32	600 V (absolute)**, so **8 modules in series (491.5 V cold) is now SAFE** — and it is what lets the full 31-panel pallet
	33	fit into the 18kPV's four string inputs. This was re-derived four independent ways (§1).
	34
	35	---
	36
	37	## 1. PV string configuration — the binding safety constraint · `scripts/01_string_sizing.py --phase2`
	38
	39	**Result: 4 strings — MPPT1 = 8S + 8S (paired), MPPT2 = 8S, MPPT3 = 7S — 31 modules, 17,825 W DC.**
	40
	41	Cold-weather open-circuit voltage (NEC 690.7) at the **−40 °C** NEK design low (same module as Phase 1), **incl. a bifacial rear-gain adder**:
	42
	43	| Quantity | Value | Check |
	44	|---|---|---|
	45	| Voc per module, −40 °C (temp only) | **61.14 V** | analytic 690.7 linear |
	46	| Voc per module, pvlib CEC single-diode | **61.26 V** | independent — agrees to **0.12 V** |
	47	| Bifacial rear-gain adder | +0.30 V | rear 0.20 × bifaciality 0.80 |
	48	| **Voc per module used (cold + bifacial)** | **61.44 V** | binding value |
	49	| **Max modules in series ≤ 550 V** | **8** | NEC 690.7 binding result |
	50	| **8S string cold Voc (longest string)** | **491.5 V** | **≤ 550 V fault ceiling (PASS, 58.5 V margin)** · ≤ 600 V abs (108.5 V) |
	51	| 9S string cold Voc | 553.0 V | **FAILS 550 V (−3.0 V); REJECTED** — would nuisance-fault the MPPT in cold weather |
	52
	53	**EG4 18kPV string-input topology (datasheet-confirmed):** 3 MPPTs, **inputs per MPPT = 2 / 1 / 1** (max 4 strings),
	54	max usable input 25 / 15 / 15 A, max Isc 31 / 19 / 19 A per MPPT. Each string is its own homerun to a dedicated input —
	55	**no combiner box** (per the datasheet). The 31-panel layout and per-MPPT validation:
	56
	57	| MPPT | Strings | Cold Voc | Cold Vmp (≤500 V) | Hot Vmp (≥140 V) | Isc vs rating | Imp vs usable | Power |
	58	|---|---|---|---|---|---|---|---|
	59	| **MPPT1** | 2 × 8S (paired, equal) | 491.5 V ✓ | 430 V ✓ | 296 V ✓ | 27.7 / 31 A ✓ | 26.2 / 25 A → **minor peak clip** | 9,200 W |
	60	| **MPPT2** | 1 × 8S | 491.5 V ✓ | 430 V ✓ | 296 V ✓ | 13.9 / 19 A ✓ | 13.1 / 15 A ✓ | 4,600 W |
	61	| **MPPT3** | 1 × 7S | 430.1 V ✓ | 376 V ✓ | 259 V ✓ | 13.9 / 19 A ✓ | 13.1 / 15 A ✓ | 4,025 W |
	62
	63	- **MPPT1 peak-current note (not a fault):** the two paralleled 8S strings draw Imp 26.2 A vs the 25 A *usable* input —
	64	the MPPT current-clips ≈ 1.2 A only at rare full-STC peaks (negligible in a Vermont winter). It is **safe**: the combined
	65	**Isc 27.7 A < 31 A MPPT1 short-circuit rating**, with 3.3 A margin.
	66	- **Array DC 17,825 W ≤ 18,000 W** max-utilized (and ≤ 21,000 W recommended). MPP voltages sit inside the 140–500 V window
	67	in all conditions (8S cold Vmp 430 V is comfortably under the 500 V MPPT-track max — note this is why the 6000XP, with its
	68	385 V MPPT max, could not have run 8S even if its voltage ceiling allowed it).
	69
	70	**Quadruple-validated (a cold-Voc error is a safety issue):**
	71	1. Analytic NEC 690.7 linear correction → module Voc **61.14 V**, 8S = 491.5 V.
	72	2. pvlib CEC six-parameter single-diode → module Voc **61.26 V** (agrees to 0.12 V).
	73	3. **vocmax** (the named NEC-690.7 tool, pinned venv) `01b_vocmax.py --phase2` → module Voc **61.14 V**, **max 8 modules ≤ 550 V**.
	74	4. **Independent adversarial agent** (re-keyed the datasheet fresh, read no project files): *"8S = 491.5 V is the correct
	75	safe maximum, clearing 550 V by 58.5 V (10.6%); 9S = 553 V must NOT be built — it overruns 550 V even before the bifacial
	76	adder (550.25 V), and 'fits under 600' is a trap because the binding constraint is 550 V."*
	77
	78	> **Carry-forward for SLD/labels:** array max system voltage = **491.5 V** (8S). Do not extend any string to 9S.
	79
	80	---
	81
	82	## 2. Conductors, voltage drop & overcurrent · `scripts/03_conductors.py --phase2`
	83
	84	NEC 690.8 design current + 310.15(B)/(C) derates + 240.4(D) + Chapter 9 Table 8 voltage drop. Tables in `scripts/nec_tables.py`.
	85
	86	| Run | Cont. current | Gauge (Cu) | Driver | Vdrop | OCPD | EGC |
	87	|---|---|---|---|---|---|---|
	88	| **PV string** array→18kPV (×4 homeruns) | Imp 13.11 A | **8 AWG** | voltage-drop | **1.33 %** @200 ft (0.99/1.33/1.66 % @150/200/250) | **none req.** (690.9(A) Exc.) | 10 AWG |
	89	| **AC output** 18kPV→main panel | 50 A | **4 AWG** | 240.4(D) | **0.13 %** | **70 A 2-pole** | 8 AWG |
	90	| **Battery per-pack** pack→busbar (×2) | 124.7 A | **2/0 AWG** | ampacity | **0.24 %** | **175 A Class-T** (each) | 6 AWG |
	91	| **Battery bank** busbar→18kPV | 249.3 A | **400 kcmil** (or 2×2/0 / 2×4/0) | ampacity | **0.31 %** | per-pack (see §3) | 4 AWG |
	92
	93	- **PV string — voltage-drop-driven, holds 8 AWG.** Four strings now share the 200 ft trench = **8 current-carrying
	94	conductors** (0.70 fill at 40 °C); 8 AWG still passes ampacity (derated 35 A ≥ 17.3 A req) and Vdrop ≤ 2 % across the full
	95	150–250 ft range. **Split into two conduits** to relax the fill (recommended). 90 °C THWN-2 / PV wire in Sched-40 PVC.
	96	- **No PV source fusing (690.9(A) Exc.):** MPPT1 parallels only **2** strings → max fault backfeed from the one other string =
	97	1.25 × Isc = **17.3 A ≤ 30 A module series fuse**. (Three or more parallel strings would require fuses.) MPPT2/3 are single strings.
	98	- **AC feeder jumps to 4 AWG / 70 A** for the 12 kW output (50 A continuous × 125 % = 62.5 A → 70 A; 240.4(D) forces 4 AWG so a
	99	70 A breaker can protect it). *(6 AWG is permissible under the 240.4(B) next-size-up rule; 4 AWG is the conservative pick and
	100	Vdrop is negligible either way.)*
	101	- **Battery bank cable:** 249 A continuous needs ≥ 312.5 A ampacity → **400 kcmil single**, or the practical **2× 2/0 (350 A)** /
	102	**2× 4/0 (460 A)** parallel sets per polarity (flexible, common for EG4, and coordinate with the 2×175 A per-pack fuses = 350 A
	103	aggregate). Each pack runs on **2/0** at 124.7 A.
	104
	105	---
	106
	107	## 3. Battery bank — discharge, C-rate, autonomy & Class-T fusing · `scripts/04_battery.py --phase2`
	108
	109	At full 12 kW AC, bank discharge = **249.3 A** (12000 ÷ 0.94 ÷ 51.2 V), **capped at the inverter's 250 A limit**, split across 2 packs.
	110
	111	**The inverter is the binding bank limit; the packs are not stressed.** The 2-pack combined BMS-honest capacity
	112	(2 × 150 A = **300 A**) and cell capacity (2 × 157 A = **314 A**) both exceed the 18kPV's **250 A** discharge cap, so:
	113
	114	| Level | Current | Limit | Margin |
	115	|---|---|---|---|
	116	| **Bank vs inverter cap** (binding) | 249.3 A | 250 A | +0.7 A — inverter sized right for 12 kW |
	117	| **Per pack vs JK-BMS OCP** (binding per-pack) | 124.7 A | 150 A (300 s) | **+25 A (17 %)** |
	118	| Per pack vs EVE cell 0.5P | 124.7 A | 157 A | +32 A |
	119	| Per pack vs JK marketed | 124.7 A | 200 A | +75 A |
	120
	121	- **C-rate:** 0.40C discharge, 0.40C charge (125 A/pack at the 250 A bank charge max) — both ≤ 0.5C. **PASS.**
	122	- **Surge (this is materially different from Phase 1):** the 18kPV's peak ratings are **minutes** long (13.5 kW w/o PV for 10 min,
	123	15.5 kW w/ PV for 5 min), not the 6000XP's 3.5 s. The battery-only 13.5 kW surge = 281 A bank → **140.3 A/pack**, which stays
	124	**under the 150 A / 300 s JK-BMS OCP** even over the full 10-minute window. The **2-pack split is what makes the minutes-long
	125	surge safe** — a single pack could not. *(Note: at low battery SOC, ~48 V, the inverter's 250 A cap limits battery-only output
	126	to ≈ 11.3 kW; full 12 kW from battery-only occurs only near nominal/high SOC. The real household load rarely approaches 12 kW.)*
	127	- **Autonomy (real Hardwick load):** 2 packs = 32.2 kWh nameplate / **25.7 kWh usable @ 80 % DoD**. Runtime 2.14 h at full 12 kW;
	128	**0.77 day at the 33.5 kWh/day average**, 0.48 day at the 54.1 kWh August peak. **NEK winter still needs the generator** for
	129	multi-day deficits (Swarm §2) — the bank is for daily cycling + surge, not deep autonomy (Swarm §6: Phase 2 = more PV, not more battery).
	130	- **Class-T fusing (per-pack = primary OCP):** **2 × 175 A Class-T** (DC-rated, 20 kAIC), one per pack, ≥ 125 % × 124.7 A and ≤ the
	131	2/0 cable's 175 A. Layered protection: the **JK-BMS** protects cells (150 A/300 s OCP, 300 A short-circuit trip), each **Class-T**
	132	protects that pack's cable and interrupts fault current. The bank conductor carries the 350 A aggregate of the two pack fuses
	133	(→ 2×2/0 / 2×4/0 / 500 kcmil coordinate).
	134	- **Multi-pack BMS comms:** 2 packs run JK-BMS **master/slave**, one master → **18kPV via CAN (a single comms link** — simpler than
	135	the two links a parallel-6000XP path needs). The 18kPV's native closed-loop is EG4-48 V; the Docan/JK pack runs via a CAN profile —
	136	**confirm on arrival** (open-loop fallback is fully viable, no battery-life penalty).
	137
	138	---
	139
	140	## 4. Production vs the real load (full pallet) · `scripts/09_phase2.py`
	141
	142	PVWatts v8, **17.82 kW**, fixed open rack (array_type 0), tilt 50°, az 180°, 14 % losses, DC:AC 1.49 (via `developer.nlr.gov`).
	143
	144	| | kWh/day | vs the Hardwick load |
	145	|---|---|---|
	146	| **Annual** | **20,962 kWh/yr** | **171 % of the 12,237 kWh/yr load** (was 79 % at Phase 1) |
	147	| December (binding) | 34.0 | vs 26.6 winter load |
	148	| Winter avg | 43.1 | — |
	149	| Summer avg | 63.9 | vs 43.4 summer / 54.1 Aug peak |
	150
	151	**Seasonal coverage (solar-only, × 0.85 usable):** winter **138 %**, summer **125 %**, **August peak 100 %** — the full pallet
	152	**meets every season including the August peak** that the 8 kW Phase-1 array missed (it covered only ~51 % of August). The MPPT1
	153	peak-clip (§1) is not modeled by PVWatts but is negligible given the array already over-produces. *(Run with a site-exact NREL
	154	key for final numbers; DEMO_KEY/documented inputs used here — immaterial to the safety calcs.)*
	155
	156	---
	157
	158	## 5. NEC 690 + 480/705/706/710 checklist · `scripts/05_nec_checklist.py --phase2`
	159
	160	**16 PASS · 2 ACTION · 1 VERIFY (BMS comms) · 1 VERIFY-AHJ (rapid shutdown) · 1 N/A (off-grid interconnection) · 1 FLAG (NFPA 855 gate).**
	161	Full section-by-section evidence in [`phase2-nec-checklist.md`](phase2-nec-checklist.md). Highlights:
	162
	163	- **690.7** max system voltage 491.5 V ≤ 550/600 V (PASS, quadruple-checked). **690.8/690.9** conductors + no PV source fusing (PASS).
	164	- **18kPV integrated protection** covers **690.11 (PV AFCI), 690.41(B) (GFDI + leakage monitor + SPD), 690.13 (integrated PV disconnect)**,
	165	and the **690.12 RSD initiator** (datasheet cites NEC 2020 — **VERIFY-AHJ** for the NEC-2023 detached ground-mount whose conductors enter the dwelling).
	166	- **706 (ESS):** 2-pack arrangement, per-pack BMS + Class-T + disconnect, bank discharge within limits (PASS); **multi-pack CAN comms = VERIFY**.
	167	- **705 = N/A** (off-grid; generator AC-IN, main panel subfed with main breaker locked off, Swarm §17).
	168	- **ACTION:** array grounding electrode (690.47) and labels/placards (690.53/54/56) — carry forward from Phase 1.
	169
	170	---
	171
	172	## 6. Diagrams (final state) · `scripts/06_schematics.py --phase2` → `artifacts/phase2/`
	173
	174	Rendered from the result JSONs so the ratings on the drawings equal the calc outputs:
	175	- **`sld.{png,svg}`** — 31-panel array → DC disconnect → **EG4 18kPV** (PV/AC/battery/gen-AC-IN) → subfed main panel, with all OCPD/
	176	disconnect/conductor ratings + GEC.
	177	- **`dc-strings.{png,svg}`** — 4 strings (8+8+8+7S) across the 3 MPPTs (MPPT1 paired), polarity, "no source fuse / max 8S (491.5 V ≤ 550 V)".
	178	- **`battery-wiring.{png,svg}`** — 18kPV ↔ DC busbar ↔ 2× Docan S3, per-pack 175 A Class-T + disconnect, bank disconnect, master/slave → CAN.
	179
	180	---
	181
	182	## Bottom line
	183
	184	The final-state configuration is electrically sound and code-compliant for off-grid NEC 2023. Selling the 6000XP for one **EG4 18kPV**
	185	deploys the **entire 31-panel pallet** at **8+8+8+7S** (491.5 V cold Voc, **58.5 V under the 550 V fault ceiling**, quadruple-verified),
	186	producing **20,962 kWh/yr (171 % of load, every season covered)**. Conductors — **8 AWG PV / 4 AWG 70 A AC / 2/0 per-pack / 400 kcmil
	187	(or 2×4/0) bank** — are all within ampacity and voltage-drop targets. The **2× Docan S3** bank delivers the inverter's full 250 A at
	188	**124.7 A/pack (17 % under the BMS OCP)**, with the 2-pack split keeping the 18kPV's minutes-long surge under the per-pack trip.
	189	Open decisions and gates — the **NFPA 855 fire-code gate** (out of scope), the 18kPV↔JK CAN profile, RSD AHJ stance, and the NREL key —
	190	are in [`phase2-open-issues.md`](phase2-open-issues.md); none change the validated electrical design.

artifacts/phase2-pathB/phase2-nec-checklist.md +33 -0

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	1	# Phase 2 — NEC 690 + 480/705/706/710 Checklist (Final State)
	2
	3	**System:** 31× Waaree 575W → EG4 18kPV-12LV → 2× Docan S3 · off-grid · NEK Vermont · **NEC 2023**.
	4	Computed by `scripts/05_nec_checklist.py --phase2` from the `*_phase2.json` results (01/03/04). Every item cites a computed value.
	5	**Summary: 16 PASS · 2 ACTION · 1 VERIFY · 1 VERIFY-AHJ · 1 N/A · 1 FLAG.**
	6
	7	| Section | Status | Topic & computed evidence |
	8	|---|---|---|
	9	| **690.7** | **PASS** | Max system voltage: longest string **8S cold Voc 491.5 V ≤ 550 V** MPPT-fault / 600 V abs (margin **58.5 V** to fault, 108.5 V to abs). Tmin −40 °C; analytic + pvlib + vocmax + independent agent agree. **9S = 553 V REJECTED** (> 550). |
	10	| **690.8(A)** | **PASS** | Max circuit current: per string Isc×1.25 = **17.3 A** (each string a dedicated homerun). MPPT1 internally combines 2 strings = **27.7 A** actual ≤ **31 A** MPPT1 Isc rating; MPPT2/3 single string ≤ 19 A. |
	11	| **690.8(B)** | **PASS** | Ampacity after 310.15 derates: PV **8 AWG** derated 35 A ≥ 17.3 A req (8 CCC, 0.70 fill); AC **4 AWG**; per-pack **2/0**; bank **400 kcmil** (or 2×2/0 / 2×4/0). |
	12	| **690.9 / 690.9(A) Ex** | **PASS** | PV source fusing **NOT required**: MPPT1 parallels only 2 strings → max backfeed 1.25×Isc = **17.3 A ≤ 30 A** module series fuse (3+ would need fuses). MPPT2/3 single string. No combiner. |
	13	| **690.9 / 240 / 480.9** | **PASS** | Battery OCP: **2× 175 A Class-T** (DC, 20 kAIC), one per pack, ≥ 125 % × 124.7 A/pack; ≤ 2/0 cable 175 A. Bank aggregate 350 A coordinated with the bank conductor. |
	14	| **690.9 / 710.15** | **PASS** | Inverter AC output OCP: **70 A 2-pole** ≥ 125 % × 50 A; protects 4 AWG (240.4(D)); EGC 8 AWG. |
	15	| **690.11** | **PASS** | DC arc-fault: EG4 18kPV **integrated PV AFCI** (690.11 / UL1699B, per datasheet). |
	16	| **690.12** | **VERIFY-AHJ** | Rapid shutdown: 18kPV **integrated RSD initiator** (datasheet cites NEC 2020:690.12). Detached ground-mount (not on a building) likely exempt, but PV/DC conductors enter the dwelling → confirm VT DPS stance for NEC 2023. |
	17	| **690.13 / 690.15** | **PASS** | Disconnects: 18kPV **integrated PV disconnect** + external load-break DC disc for service; **2 per-pack disconnects + a 250 A-class bank disconnect** within sight. |
	18	| **690.41(B)** | **PASS** | System grounding / GFDI: 18kPV **integrated PV ground-fault monitoring** + pole-sensitive leakage-current monitor + integrated SPD. |
	19	| **690.43 / 690.45** | **PASS** | EGCs (250.122): PV 10 AWG (no source OCPD), per-pack **6 AWG** (175 A), AC **8 AWG** (70 A), bank 4 AWG. Bond array frames + enclosures + battery busbar. |
	20	| **690.47** | **ACTION** | Array grounding electrode: drive a ground rod, **6 AWG Cu GEC** bonded to the dwelling GES (690.47(A)). Carry forward from Phase 1; verify for the expanded footprint. |
	21	| **690.31** | **PASS** | Wiring methods: PV in Sched-40 PVC conduit (squirrel/UV, Swarm §16); **8 AWG THWN-2 / PV wire 90 °C**. 4 strings → split across 2 conduits to relax the 8-CCC fill. |
	22	| **705** | **N/A** | No utility interconnection (off-grid, no 705.12 backfeed). Generator AC-IN to the 18kPV (200 A bypass / 90 A gen), main panel subfed with main breaker locked off (Swarm §17); transfer internal to the hybrid. |
	23	| **706.7 / 706.20** | **PASS** | ESS multi-pack: 2× Docan S3 (JK-PB2A16S20P BMS) in parallel on a DC busbar; each pack own BMS + Class-T + disconnect. Bank 249 A split **124.7 A/pack** — within the 150 A/300 s JK OCP (**17 % headroom**) and 157 A cell limit. C-rate 0.40C. |
	24	| **706.30 / 480.7** | **PASS** | ESS disconnecting means: per-pack disconnects + lockable bank disconnect within sight; the 18kPV battery port is the inverter-side disconnect; BMS opens on cell faults. |
	25	| **706.31 / 480.9** | **PASS** | ESS OCP: per-pack 175 A Class-T (20 kAIC > pack fault). Layered: JK-BMS (150 A/300 s OCP, 300 A SC) protects cells; Class-T protects each pack cable. |
	26	| **706.x / BMS comms** | **VERIFY** | Multi-pack comms: 2 packs JK-BMS master/slave, one master → 18kPV via **CAN (single link)**. 18kPV native closed-loop is EG4-48 V; Docan/JK via a CAN profile → **confirm on arrival**. Open-loop fallback fully viable. |
	27	| **710.15** | **PASS** | Stand-alone output: 18kPV 12 kW 120/240 V split-phase, output 50 A; off-grid, no backfeed. Continuous 8000 W/120 V leg covers the household peak; surge 13.5 kW (w/o PV). |
	28	| **690.53/54/56 / 110.21** | **ACTION** | Labels/placards: max system voltage **491.5 V** (690.53), inverter output 12 kW/50 A (690.54), RSD placard if AHJ requires (690.56(C)), DC disconnect + directory, per-pack battery hazard labels. |
	29	| **NFPA 855 / VT 2025 Fire Code** | **FLAG (OUT OF SCOPE)** | 2 packs = **32.2 kWh nameplate**. Swarm §4: even 2 packs (32 kWh) likely crosses the 20 kWh residential threshold (3 packs/48 kWh definitively) → detached non-combustible shed ≥ 10 ft, UL 9540 listing or AHJ hazard-mitigation analysis, + propane-heater combustion-air/ventilation/separation. **Not engineered here — pre-clear with VT DPS in writing before ordering the 2nd pack.** |
	30	| **Voltage drop (design target)** | **PASS** | DC **1.33 %** (150–250 ft: 0.99/1.33/1.66 %); per-pack 0.24 %; bank 0.31 %; AC 0.13 %. (Informational; not NEC-mandated.) |
	31
	32	**Carry-forward from Phase 1 (unchanged):** the array grounding electrode (690.47) and label set (690.53/54/56) remain the two ACTION
	33	items; both are produced from the computed ratings above before inspection.

artifacts/phase2-pathB/phase2-open-issues.md +64 -0

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	1	# Phase 2 — Open Issues, Assumptions & Datasheet Gaps
	2
	3	Nothing here changes the validated final-state design (see `phase2-design.md`); these are items to confirm/measure,
	4	flagged assumptions, datasheet gaps where I stated a defensible value, and the **out-of-scope gates**.
	5
	6	## A. Confirm before buying wire / energizing
	7
	8	1. **Run lengths — confirmed by owner (2026-06-03):** battery **adjacent (~10 ft, designed at 10)**; remaining 17 panels
	9	**co-located with the Phase-1 array, reusing the 150–250 ft trench (designed at 200 ft, swept 150/200/250)**. 8 AWG PV holds
	10	≤ 2 % across the whole range; measure the actual trench for *wire quantity*, not gauge.
	11	2. **AC subfeed at 50 A / 70 A (Swarm §17).** The 12 kW output is now **50 A / 70 A 2-pole on 4 AWG** (up from Phase-1's 25 A/35 A/8 AWG).
	12	Confirm the existing main panel's input lugs accept 4 AWG and a 70 A feed, and that its main breaker is lockable-off for the subfed arrangement.
	13	3. **18kPV ↔ JK/Docan closed-loop comms (CAN).** The 18kPV's native closed-loop is EG4-48 V; the Docan/JK-PB2A16S20P pack runs via a
	14	CAN profile. With 2 packs: JK master/slave, one master → 18kPV (a **single** comms link). **Confirm the profile on arrival;**
	15	open-loop fallback is fully viable (no battery-life penalty). *(VERIFY item on the NEC checklist.)*
	16	4. **690.12 rapid shutdown — AHJ stance (VERIFY-AHJ).** 18kPV has an integral RSD initiator (datasheet cites NEC 2020:690.12);
	17	VT is NEC 2023. Detached ground-mount likely exempt, but PV conductors enter the dwelling — **get the VT DPS inspector's position in writing.**
	18	5. **Sell the EG4 6000XP.** Path B economics assume ~$800–1,000 resale (Swarm §10). Confirm before committing; the 6000XP comes out
	19	of service when the 18kPV is energized (single-inverter swap, not a parallel addition).
	20
	21	## B. Inputs substituted with a defensible value (no datasheet/owner confirmation)
	22
	23	6. **NREL API key — not provided.** Production (`09_phase2.py`) ran on the documented inputs / DEMO_KEY → 20,962 kWh/yr. Rerun with
	24	your key for site-exact numbers; immaterial to the safety calcs. Cold-Voc uses the documented **−40 °C** NEK low (conservative;
	25	an NSRDB pull would only loosen it). Host verified empirically as `developer.nlr.gov`.
	26	7. **Exact site lat/lon** (used 44.5, −72.0) and **tilt 50° / azimuth 180°** — affect production only; confirm for site-exact energy.
	27
	28	## C. Datasheet gaps / vendor caveats (18kPV-specific)
	29
	30	8. **No published per-MPPT power cap on the 18kPV.** Only the per-MPPT *current* limits are given (25/15/15 A usable). **MPPT1 carries
	31	16 panels (9.2 kW)** — its paired 8S strings draw Imp **26.2 A > the 25 A usable** limit, so the MPPT current-clips ≈ 1.2 A at rare
	32	full-STC peaks. **Safe** (combined Isc 27.7 A < 31 A MPPT1 rating), a small harvest cap, not a fault. If you prefer zero clipping,
	33	move ~1 panel off MPPT1 (e.g. 7+7 / 8 / 8 with one panel spare) — but the array already over-produces (§4 of the design).
	34	9. **18kPV surge battery current is not datasheet-stated.** The peak ratings are given in AC watts over **minutes** (13.5 kW w/o PV /10 min,
	35	15.5 kW w/ PV /5 min), not as a battery current. I assumed the **250 A discharge is continuous** and that the battery-side surge is
	36	bounded by it: battery-only 13.5 kW = 281 A bank → **140 A/pack < the 150 A/300 s BMS OCP**, so no nuisance trip even over 10 minutes.
	37	The **2-pack split is what makes this safe** (a single pack at 281 A would trip). Confirm if EG4 publishes a separate battery surge figure.
	38	10. **Full 12 kW battery-only is SOC-dependent.** At low SOC (~48 V) the 250 A cap limits battery-only output to ≈ 11.3 kW; full 12 kW
	39	from battery-only requires near-nominal/high SOC. The real Hardwick load rarely approaches 12 kW (Aug peak ≈ 54 kWh/day ≈ 2.25 kW avg),
	40	so this is a corner case, not an operating constraint.
	41	11. **Battery bank cable & fusing are engineer-selected** (no vendor spec). Bank conductor: **400 kcmil single** (335 A) or **2× 4/0 / 2× 2/0**
	42	parallel (recommended — flexible, low-loss, and coordinates with the 350 A aggregate of the two 175 A pack fuses). Per-pack **175 A Class-T**
	43	is the primary OCP (computed in `04`).
	44	12. **Verify the module SKU at receiving** — confirm **BiN-08-575 (Voc 52.30 V, 144-cell)**, same as Phase 1; a different SKU corrupts the cold-Voc.
	45
	46	## D. Out-of-scope gates (flagged, NOT engineered here)
	47
	48	13. **NFPA 855 / VT 2025 Fire Code — the single biggest non-electrical gate.** 2 packs = **32.2 kWh nameplate**. Per **Swarm §4**, even
	49	2 packs likely cross the **20 kWh residential aggregate threshold** (3 packs / 48 kWh definitively). Triggers: detached non-combustible
	50	battery shed ≥ 10 ft from the dwelling, **UL 9540 listing or an AHJ-approved Hazard Mitigation Analysis** for the unlisted Docan pack,
	51	and combustion-air / ventilation / fire-separation handling for the **propane heater in a Li-battery enclosure**. **Pre-clear with the
	52	VT DPS Division of Fire Safety in writing before ordering the 2nd pack.** *(This is the item most likely to be told "no" by the AHJ or insurer.)*
	53	14. **Insurance disclosure (Swarm §7).** Disclose the DIY + non-UL ESS (chemistry/kWh/location) to the carrier in writing; if excluded, shop
	54	Co-op Insurance (Middlebury). Out of electrical scope.
	55	15. **Generator (Phase-1 infrastructure).** Assumed AC-IN to the 18kPV (200 A AC bypass / 90 A generator input), L14-30 inlet + interlock,
	56	gen-assist charging on low SOC. Selection/sizing is not in electrical scope.
	57	16. **Battery shed / structure / racking / trenching civil** — out of scope (owner handles mounting/housing).
	58
	59	## E. Validation status of the safety-critical result
	60
	61	The full-pallet cold-Voc result (**8S, 491.5 V ≤ 550 V fault / 600 V abs**) is confirmed by **four independent methods**: analytic NEC 690.7,
	62	pvlib CEC single-diode, **vocmax** (the named tool, offline), and an **independent adversarial agent** that re-keyed the datasheet from scratch
	63	(read no project files) and reproduced 61.14 V/module → 491.5 V at 8S, confirming 8S safe and **9S (553 V) rejected**. The only vocmax capability
	64	not exercised is its NSRDB statistical worst-case, which needs the NREL key (item 6) and would only relax the already-conservative −40 °C result.

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	1849	<!-- Bank 252A @12kW → 126A/pack (17% under 150A BMS) + 126A/inverter (14A under 140A) · 0.401C · 4× 175A Class-T · 2× JK-BMS → CAN (one per inverter) -->
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	1429	<!-- 7S (+) -->
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	1531	<!-- 7S (+) -->
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artifacts/phase2/phase2-bom.md +43 -0

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	1	# Phase 2 — **Path-A** Bill of Materials (2× EG4 6000XP, 28 panels + 3 spares)
	2
	3	Quantities **computed** (`11_pathA.py`, conductors via the validated `03` sizing); dollar figures are **labeled
	4	ESTIMATES** (Swarm §10 / Key Decisions / `09_phase2.py`). **Panels $0** (owned). Structure / shed / fire code out of scope.
	5
	6	## Major equipment
	7
	8	| Item | Qty | Computed basis | Cost (estimate) |
	9	|---|---|---|---|
	10	| **EG4 6000XP** inverter (added; keep the existing one → 2 total) | +1 | 2×6 kW AC / 2×8 kW PV / 2×140 A batt; 4 MPPT host 4×7S | **$1,549 + ~$150 parallel kit ≈ $1,699** |
	11	| **Docan S3 16 kWh** pack (added → 2 total) | +1 | 2 packs = 25.7 kWh usable; 126 A/pack ≤ 150 A BMS | **$1,758 – 2,000** |
	12	| **Waaree 575W** panels — **28 wired + 3 SPARES** | 31 (3 reserve) | 4×7S = 16.1 kW (`11`); spares replace failed Grade-B modules | **$0** (owned) |
	13
	14	*No 6000XP resale (you keep the Phase-1 unit) — that's the ~$1,900 saving vs Path B's 18kPV swap.*
	15
	16	## Balance of system (computed gauges/ratings; estimated $)
	17
	18	| Item | Qty / spec | Computed basis (`11`) |
	19	|---|---|---|
	20	| PV wire **8 AWG** THWN-2/PV + **10 AWG** EGC | ~1,600 ft (4 strings × 2 × 200 ft) | 1.33 % @200 ft, 8 CCC; reuse Phase-1's ~800 ft |
	21	| AC per-unit **8 AWG** + **35 A 2-pole** breaker | 2 sets (one per 6000XP) | 25 A × 125 % → 35 A (= Phase-1) |
	22	| AC combined feeder **4 AWG** + **70 A 2-pole** | ~10 ft | 50 A × 125 % → 70 A; 240.4(D) |
	23	| **EG4 parallel kit / comms cabling** | 1 | combine 2× 6000XP outputs + sync |
	24	| **AC combiner busbar / small subpanel** | 1 | combine 2× 35 A → 70 A feed |
	25	| Battery **2/0** Cu (per-pack ×2 + per-inverter ×2) + **6 AWG** EGC | 4 short sets | 126 A each; busbar topology (no 400 kcmil needed) |
	26	| **DC busbar, 250 A** | 1 | 2 packs in + 2 inverters out |
	27	| **175 A Class-T** fuse + holder (DC, 20 kAIC) | **4** (2 packs + 2 inverter inputs) | per-pack + per-6000XP-input OCP |
	28	| **Bank disconnect 250 A DC** + per-pack/per-inverter disconnects | set | 690.15 / 706.30 / 480.7 |
	29	| 2nd PV conduit (Sched-40 PVC) | ~200 ft | split 8 CCC → 2 conduits |
	30	| Lugs, MC4, labels/placards | set | from computed ratings |
	31
	32	## Cost roll-up (ESTIMATE)
	33
	34	| Line | Estimate |
	35	|---|---|
	36	| +1 EG4 6000XP (with parallel kit) | $1,699 |
	37	| +1 Docan S3 pack | $1,758 – 2,000 |
	38	| 28 panels wired + 3 spares | $0 (owned) |
	39	| BoS (PV/AC/battery wire, parallel kit, busbar, 4× Class-T, 2×35 A + 70 A breakers, disconnects, conduit, lugs) | $800 – 1,500 |
	40	| **Total added (Path A)** | **≈ $4,260 – 5,200** |
	41
	42	**≈ $1,900 less than Path B** (~$6,060–7,200). Path A keeps the existing 6000XP (no resale risk), adds an N+1 second inverter,
	43	and reserves 3 spare panels — trading ~9 % production and some August-peak margin for cost, redundancy, and spares.

artifacts/phase2/phase2-design.md +121 -0

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	1	# PRSM Off-Grid Solar — Phase 2 / **SELECTED BUILD: Path A** (2× EG4 6000XP)
	2
	3	> **STATUS — SELECTED (owner decision, 2026-06-03).** This is the chosen final-state build. The **Path B (1× EG4 18kPV)**
	4	> design is **retained as the documented alternative** in [`../phase2-pathB/`](../phase2-pathB/phase2-design.md). §6 has the A-vs-B comparison.
	5
	6	**Wires 28 of the 31 panels (4×7S, 16.1 kW)** to **two paralleled EG4 6000XP** inverters; the **3 remaining panels are held as
	7	field spares** (to replace a cracked/degraded Grade-B module without re-sourcing the SKU). Owner's other choices unchanged:
	8	**2× Docan S3**, battery adjacent (~10 ft), 200 ft trench. Off-grid · NEK Vermont · **NEC 2023**.
	9	**Date:** 2026-06-03 · Computed by `scripts/11_pathA.py` (conductors reuse the validated `03` sizing) + `scripts/10_compare_inverter_paths.py` (production). Every load-bearing number is script-computed and cited.
	10
	11	> Reproduce: `~/.venvs/prsm-electrical/bin/python scripts/11_pathA.py` then `scripts/06_schematics.py --pathA`.
	12	> Results: `artifacts/results/11_pathA.json`, `10_compare.json`. Diagrams: this folder (`sld`, `dc-strings`, `battery-wiring`).
	13
	14	---
	15
	16	## 1. PV strings — the validated Phase-1 7S, replicated ×4
	17
	18	**4 strings of 7S** (one per MPPT, 2 MPPTs per 6000XP), 28 modules, **16.1 kW DC**. String safety is **identical to the
	19	quadruple-validated Phase-1 result** (same module, same 6000XP 480/500 V ceilings):
	20
	21	| Quantity | Value | Check |
	22	|---|---|---|
	23	| 7S string cold Voc (−40 °C + bifacial) | **430.1 V** | **≤ 480 V design (PASS, 50 V margin)** · ≤ 500 V abs (70 V) |
	24	| Per MPPT (1 string) | Isc 13.87 A / Imp 13.11 A | ≤ 25 A Isc rating / ≤ 17 A input ✓ |
	25	| String power | 4,025 W | ≤ 5,000 W oversize cap (≈25 W clip at STC) |
	26	| Array DC | 16,100 W | vs 16,000 W usable (2×8 kW) — essentially at the cap |
	27
	28	No 8S anywhere; the lower 430 V string voltage sits **50 V further from its ceiling** than Path B's 491.5 V. **No PV source
	29	fusing** (exactly 1 string per MPPT → no parallel strings to backfeed). No combiner.
	30
	31	## 2. Conductors · `scripts/11_pathA.py` (NEC 690.8 / 310.15 / 240.4 / Ch.9 T8)
	32
	33	| Run | Current | Gauge (Cu) | Driver | Vdrop | OCPD |
	34	|---|---|---|---|---|---|
	35	| **PV string** array→6000XP (×4 homeruns) | 13.11 A | **8 AWG** | voltage-drop | 1.33 % @200 ft | none (690.9(A)) |
	36	| **AC per-unit** 6000XP→combiner (×2) | 25 A | **8 AWG** | 240.4(D) | 0.16 % | **35 A 2-pole** (each) |
	37	| **AC combined** combiner→main panel | 50 A | **4 AWG** | 240.4(D) | 0.13 % | **70 A 2-pole** |
	38	| **Battery per-pack** pack→busbar (×2) | 126 A | **2/0** | ampacity | 0.24 % | 175 A Class-T |
	39	| **Battery per-inverter** busbar→6000XP (×2) | 126 A | **2/0** | ampacity | 0.48 % | 175 A Class-T |
	40
	41	**Cleaner battery cabling than Path B:** because the 12 kW load splits across **two** inverter inputs (126 A each), every
	42	battery cable is **2/0** — there is no single 250 A run, so **no 400 kcmil / parallel-4/0** is needed. The bank busbar (250 A+)
	43	is fed by 2 packs (126 A each) and feeds 2 inverters (126 A each). AC: each 6000XP has its own **35 A/8 AWG** output combining
	44	at the parallel busbar to **70 A/4 AWG** for the main-panel feed.
	45
	46	## 3. Battery bank · `scripts/11_pathA.py`
	47
	48	At 12 kW the bank delivers **252 A** (eff 0.93), split 126 A/pack and 126 A/inverter:
	49
	50	| Level | Current | Limit | Margin |
	51	|---|---|---|---|
	52	| Bank vs **2×140 A inverter limit** | 252 A | **280 A** | **+28 A (10 %)** — more than Path B's 0.7 A |
	53	| Per inverter vs one 6000XP | 126 A | 140 A | +14 A — identical to validated Phase 1 |
	54	| Per pack vs JK-BMS OCP (binding) | 126 A | 150 A (300 s) | **+24 A (17 %)** |
	55	| Per pack vs EVE cell 0.5P | 126 A | 157 A | +31 A |
	56
	57	- **C-rate** 0.40C discharge / 0.40C charge (250 A bank charge ÷ 2). **PASS.**
	58	- **Surge:** 2×12 kW/**3.5 s** = 504 A bank → 252 A/pack — above the 150 A OCP and 157 A cell, but **3.5 s ≪ the 300 s OCP delay**
	59	and **< the 300 A short-circuit trip**, so it's a safe transient (same logic as Phase 1; brief vs the 18kPV's minutes-long surge).
	60	- **Autonomy:** identical to Path B — **25.7 kWh usable**, 0.77 day @ avg / 0.48 day @ peak; generator backfills.
	61	- **Class-T fusing: 4× 175 A** (one per pack + one per 6000XP battery input, per the 6000XP manual), DC-rated, 20 kAIC, ≤ 2/0 cable 175 A. Layered with each JK-BMS.
	62	- **Comms: TWO JK→Pylontech-CAN links** (one per 6000XP) to configure (Swarm §9). Open-loop fallback fully viable.
	63
	64	## 4. Production vs load · `scripts/10_compare_inverter_paths.py`
	65
	66	**19,213 kWh/yr = 157 % of the 12,237 kWh/yr load** (PVWatts v8, 16.1 kW, same site/tilt/azimuth as Phase 1).
	67
	68	| Coverage (solar-only ×0.85) | Winter | Summer | **August peak** |
	69	|---|---|---|---|
	70	| Path A (16.1 kW) | 128 % ✓ | 113 % ✓ | **91 %** — short |
	71	| (Path B reference, 17.8 kW) | 138 % | 125 % | 100 % |
	72
	73	Winter (Dec 31.3 kWh/day vs 26.6 load) and summer are fully covered. **The single August peak day is ~91 %** on solar-only
	74	with the conservative 0.85 round-trip factor — much of August load is daytime cooling used directly (no round-trip), and the
	75	battery + generator backfill any genuine gap, so it's a *margin* difference, not a failure. Production is **1,749 kWh/yr (9 %)
	76	less than Path B** — immaterial to the annual balance.
	77
	78	## 5. NEC checklist (deltas vs Path B) · `scripts/11_pathA.py`
	79
	80	| Section | Status | Evidence |
	81	|---|---|---|
	82	| 690.7 | PASS | Max system voltage **430.1 V (7S)** ≤ 480 V design / 500 V abs (validated ×4). |
	83	| 690.8(A) | PASS | Per string Isc×1.25 = 17.3 A; 1 string/MPPT → Isc 13.87 A ≤ 25 A, Imp 13.11 A ≤ 17 A. |
	84	| 690.9(A) Ex | PASS | **No PV source fusing** — exactly 1 string per MPPT (no parallel strings). |
	85	| 690.9 / 710.15 | PASS | AC OCPD: **2× 35 A 2-pole** (8 AWG) at the parallel busbar; **combined 70 A** (4 AWG) to the panel. |
	86	| 690.11 / 690.41(B) | PASS | Each 6000XP integrated PV AFCI + GFDI/isolation (×2 units). |
	87	| 690.12 | VERIFY-AHJ | Each 6000XP supplies an RSD initiator if required (same AHJ question as Phase 1 / Path B). |
	88	| 690.13 / 690.15 | PASS | Each 6000XP integrated DC disconnect; bank + per-pack + per-inverter disconnects. |
	89	| 690.9 / 480.9 / 706.31 | PASS | **4× 175 A Class-T** (2 packs + 2 inverter inputs), 20 kAIC, ≤ 2/0 cable 175 A. |
	90	| 705 | N/A | Off-grid; two inverters **paralleled** (EG4 parallel kit), not utility-interactive; main panel subfed, main off. |
	91	| 706.7 | PASS | 2-pack bank on a busbar feeding 2 inverters; 252 A split 126 A/pack (17 % under BMS) + 126 A/inverter (14 A under 140 A). |
	92	| 706.x comms | VERIFY | **Two** JK→Pylontech-CAN links to configure (vs one for Path B). Open-loop fallback viable. |
	93	| Redundancy | NOTE | **N+1**: one 6000XP can keep ~half the system (8 kW PV / 6 kW AC) running if the other fails. |
	94	| 690.53/54/56 | ACTION | Labels: max system voltage 430 V, 2× inverter output ratings, disconnects, battery hazard. |
	95	| NFPA 855 | FLAG | Same gate as Path B — 2 packs (32 kWh) per Swarm §4 may cross the 20 kWh threshold; out of scope. |
	96
	97	## 6. Path A vs Path B — the tradeoff (both script-computed)
	98
	99	| | **Path A** (2×6000XP / 28 / 4×7S) | **Path B** (18kPV / 31) |
	100	|---|---|---|
	101	| Panels wired / **spares** | 28 / **3 spares** | 31 / 0 |
	102	| Production | 19,213 kWh (157 %) | 20,962 kWh (171 %) |
	103	| August peak coverage | 91 % | 100 % |
	104	| Battery limit headroom | **+28 A** (280 A) | +0.7 A (250 A) |
	105	| String cold Voc | 430 V (50 V margin) | 491.5 V (58.5 V margin) |
	106	| Inverters / comms links | 2 / **2** | 1 / **1** |
	107	| PV future headroom | −100 W (maxed) | +180 W |
	108	| Redundancy | **N+1 (one unit survives)** | single point of failure |
	109	| Cost (estimate) | **baseline** | +~$1,900 |
	110
	111	**Path A was selected** for spare panels + inverter redundancy + lower cost + a more-conservative 7S string, accepting 9 % less
	112	production and a slightly battery/generator-dependent August peak. **Path B** (the retained alternative in
	113	[`../phase2-pathB/`](../phase2-pathB/phase2-design.md)) trades that for full August coverage, future PV headroom, single comms, and
	114	one clean enclosure at +~$1,900. For this remote, off-grid, Grade-B, generator-backed site, **Path A is the better fit** — the
	115	"reserved" 3 panels become insurance, and the August gap is covered by infrastructure (battery + generator) that exists anyway.
	116
	117	---
	118
	119	**Deliverables (this folder = the selected build):** [`phase2-design.md`](phase2-design.md) · [`phase2-nec-checklist.md`](phase2-nec-checklist.md) · [`phase2-bom.md`](phase2-bom.md) · [`phase2-open-issues.md`](phase2-open-issues.md) · diagrams [`sld`](sld.png) / [`dc-strings`](dc-strings.png) / [`battery-wiring`](battery-wiring.png) (PNG + SVG).
	120	**Retained alternative:** Path B (1× EG4 18kPV) in [`../phase2-pathB/`](../phase2-pathB/phase2-design.md).
	121	**Out of scope (flagged, same as Path B):** NFPA 855 / fire code, battery shed/structure, generator selection, pricing beyond estimate.

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	1	# Phase 2 — NEC Checklist (SELECTED BUILD: Path A, 2× EG4 6000XP)
	2
	3	**System:** 28× Waaree 575W (4×7S) → 2× EG4 6000XP (parallel) → 2× Docan S3 · off-grid · NEK Vermont · **NEC 2023**.
	4	Computed by `scripts/11_pathA.py` from the validated string (`01`) + the reused `03` conductor sizing. Every item cites a computed value.
	5	*(Path B / 18kPV is the retained alternative — its checklist is in [`../phase2-pathB/phase2-nec-checklist.md`](../phase2-pathB/phase2-nec-checklist.md).)*
	6
	7	| Section | Status | Topic & computed evidence |
	8	|---|---|---|
	9	| **690.7** | **PASS** | Max system voltage: **7S cold Voc 430.1 V ≤ 480 V** design / 500 V abs (margin **50 V** / 70 V). Same module + 6000XP ceilings as Phase 1; **quadruple-validated** (analytic + pvlib + vocmax + independent agent). Replicated ×4 strings. |
	10	| **690.8(A)** | **PASS** | Max circuit current: per string Isc×1.25 = **17.3 A**; exactly 1 string/MPPT → Isc 13.87 A ≤ **25 A** MPPT rating, Imp 13.11 A ≤ **17 A** input. |
	11	| **690.8(B)** | **PASS** | Ampacity after 310.15 derates: PV **8 AWG** (8 CCC, 0.70 fill); AC per-unit **8 AWG** / combined **4 AWG**; battery all **2/0**. |
	12	| **690.9 / 690.9(A) Ex** | **PASS** | **No PV source fusing** — exactly 1 string per MPPT (no parallel strings) on either 6000XP, so no backfeed can exceed the 30 A module fuse. No combiner. |
	13	| **690.9 / 240 / 480.9** | **PASS** | Battery OCP: **4× 175 A Class-T** (DC, 20 kAIC) — one per pack + one per 6000XP battery input — ≥ 125 % × 126 A; ≤ 2/0 cable 175 A. |
	14	| **690.9 / 710.15** | **PASS** | AC OCPD: **2× 35 A 2-pole** (8 AWG) per 6000XP at the parallel busbar; **combined 70 A 2-pole** (4 AWG) to the main panel. |
	15	| **690.11** | **PASS** | DC arc-fault: each 6000XP integrated PV AFCI (×2 units). |
	16	| **690.12** | **VERIFY-AHJ** | Rapid shutdown: each 6000XP supplies an RSD initiator if required. Detached ground-mount likely exempt, but conductors enter the dwelling → confirm VT DPS stance (same question as Phase 1). |
	17	| **690.13 / 690.15** | **PASS** | Disconnects: each 6000XP integrated DC disconnect; **bank disconnect + 2 per-pack + 2 per-inverter** disconnects, within sight. |
	18	| **690.41(B)** | **PASS** | System grounding / GFDI: each 6000XP integrated PV ground-fault / isolation monitoring (×2 units). |
	19	| **690.43 / 690.45** | **PASS** | EGCs (250.122): PV 10 AWG, per-pack & per-inverter **6 AWG** (175 A), AC per-unit 10 AWG / combined 8 AWG (70 A). Bond array frames + enclosures + busbar. |
	20	| **690.47** | **ACTION** | Array grounding electrode: drive a rod, 6 AWG Cu GEC bonded to the dwelling GES (690.47(A)). Carry forward from Phase 1. |
	21	| **690.31** | **PASS** | Wiring methods: PV in Sched-40 PVC conduit (squirrel/UV, Swarm §16); 8 AWG THWN-2 / PV 90 °C; 4 strings → split across 2 conduits. |
	22	| **705** | **N/A** | Off-grid; the two inverters are **paralleled via the EG4 parallel kit** (not utility-interactive). Generator AC-IN; main panel subfed, main breaker locked off (Swarm §17). |
	23	| **706.7 / 706.20** | **PASS** | ESS: 2× Docan S3 on a DC busbar feeding **2 inverters**; bank 252 A split **126 A/pack** (17 % under the 150 A BMS OCP, 157 A cell) + **126 A/inverter** (14 A under the 140 A 6000XP limit — identical to validated Phase 1). C-rate 0.40C. |
	24	| **706.30 / 480.7** | **PASS** | ESS disconnecting means: bank + per-pack + per-inverter disconnects (lockable, within sight); each 6000XP battery port is its inverter-side disconnect; each JK-BMS opens on cell faults. |
	25	| **706.31 / 480.9** | **PASS** | ESS OCP: 4× 175 A Class-T, 20 kAIC. Layered: each JK-BMS (150 A/300 s OCP, 300 A SC) protects cells; Class-T protects each cable. |
	26	| **706.x / BMS comms** | **VERIFY** | **TWO** JK→Pylontech-CAN links (one per 6000XP) to configure (Swarm §9: ~2–4 hrs each, intermittent CAN drops). Open-loop fallback fully viable (no battery-life penalty). |
	27	| **Parallel inverters** | **VERIFY** | The two 6000XP units must run **compatible firmware** and share the EG4 parallel/comms kit; confirm versions match on arrival. |
	28	| **710.15** | **PASS** | Stand-alone output: 2× 6000XP paralleled = 12 kW 120/240 V split-phase, 50 A combined; off-grid, no backfeed. |
	29	| **690.53/54/56 / 110.21** | **ACTION** | Labels/placards: max system voltage **430 V** (690.53), **2× inverter output ratings** (690.54), RSD placard if AHJ requires, disconnects + directory, per-pack battery hazard. |
	30	| **Redundancy (resilience NOTE)** | **NOTE** | **N+1:** if one 6000XP fails, the other can keep ~half the system (8 kW PV / 6 kW AC) running — a real off-grid benefit vs a single inverter. |
	31	| **NFPA 855 / VT 2025 Fire Code** | **FLAG (OUT OF SCOPE)** | 2 packs = **32.2 kWh nameplate** — per Swarm §4 likely crosses the 20 kWh residential threshold → detached non-combustible shed ≥ 10 ft, UL 9540 or AHJ HMA, propane-enclosure ventilation. **Not engineered — pre-clear with VT DPS before ordering the 2nd pack.** |
	32	| **Voltage drop (target)** | **PASS** | PV 1.33 %; per-pack 0.24 %; per-inverter 0.48 %; AC per-unit 0.16 % / combined 0.13 %. (Informational.) |
	33
	34	**Summary: ~17 PASS · 2 ACTION · 2 VERIFY (BMS comms, parallel firmware) · 1 VERIFY-AHJ (RSD) · 1 N/A · 1 FLAG (NFPA 855), + N+1 redundancy note.**

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	1	# Phase 2 — Open Issues, Assumptions & Gates (SELECTED BUILD: Path A, 2× EG4 6000XP)
	2
	3	Nothing here changes the validated Path-A design (see [`phase2-design.md`](phase2-design.md)); these are items to confirm/measure,
	4	flagged assumptions, and the out-of-scope gates. *(Path B / 18kPV is the retained alternative in [`../phase2-pathB/`](../phase2-pathB/phase2-open-issues.md).)*
	5
	6	## A. Confirm before buying wire / energizing
	7
	8	1. **Run lengths — confirmed by owner (2026-06-03):** battery **adjacent (~10 ft)**; 28 wired panels **co-located with the Phase-1
	9	array, reusing the 150–250 ft trench (designed 200 ft, swept)**. 8 AWG PV holds ≤ 2 % across the range; measure for wire *quantity*.
	10	2. **AC subfeed (Swarm §17).** Path A produces **2× 25 A (35 A/8 AWG) unit outputs combining to 50 A (70 A/4 AWG)** at the parallel
	11	busbar. Confirm the AC combiner/parallel arrangement and that the existing main panel accepts the 70 A feed with its main breaker lockable-off.
	12	3. **EG4 parallel kit + matched firmware (Path-A specific).** The two 6000XP units must share the EG4 parallel/comms kit and run
	13	**compatible firmware**. Confirm the kit part number and that both units' firmware versions match on arrival.
	14	4. **TWO JK→Pylontech-CAN comms links (Path-A specific, Swarm §9).** One per 6000XP — budget ~2–4 hrs each (CAN ID, 500 kbps, termination).
	15	Known intermittent CAN drops auto-recover to voltage-only. **Open-loop fallback fully viable.** (Path B needs only one link — a real simplicity edge for B.)
	16	5. **690.12 rapid shutdown — AHJ stance (VERIFY-AHJ).** Each 6000XP has an RSD initiator; get the VT DPS inspector's position in writing for the detached ground-mount.
	17	6. **Keep the existing 6000XP.** Path A adds a *second* 6000XP (no resale of the first) — confirm the existing unit's firmware/health before paralleling.
	18
	19	## B. Inputs substituted with a defensible value
	20
	21	7. **NREL API key — not provided.** Production (`10_compare_inverter_paths.py`) ran on documented inputs / DEMO_KEY → **19,213 kWh/yr**
	22	(cached in `artifacts/results/10_compare.json`). A fresh re-run needs the DEMO_KEY rate limit to clear or a real key (`developer.nrel.gov`,
	23	host `developer.nlr.gov`). Immaterial to the safety calcs; cold-Voc uses the conservative documented −40 °C.
	24	8. **Exact site lat/lon** (44.5, −72.0) and **tilt 50° / azimuth 180°** — affect production only; confirm for site-exact energy.
	25
	26	## C. Path-A design notes / caveats
	27
	28	9. **August peak is ~91 % solar-covered** (vs Path B's 100 %) — the 16.1 kW array is 9 % smaller. With the conservative 0.85
	29	round-trip factor; daytime cooling load used directly (no round-trip) makes the real coverage higher, and the **battery + generator
	30	backfill** the gap. December and all other months are fully covered (Dec 31.3 vs 26.6 load). Accepted tradeoff for the spares/redundancy/cost.
	31	10. **PV input is essentially maxed (−100 W):** 16.1 kW DC on 16 kW usable (2× 8 kW). **No room to add more PV later** without a third
	32	inverter — a deliberate consequence of holding 3 panels as spares rather than wiring them.
	33	11. **3 spare panels — store properly.** Keep the 3 reserved Waaree modules dry, supported, and labeled; verify they match the wired
	34	batch (BiN-08-575, Voc 52.30 V) at receiving so a future swap is plug-compatible.
	35	12. **Battery cabling & fusing are engineer-selected** (no vendor spec). All battery cables are **2/0** (busbar topology — no 400 kcmil
	36	needed since the load splits across 2 inverters). **4× 175 A Class-T** (2 packs + 2 inverter inputs), 20 kAIC.
	37	13. **Surge is a 3.5 s transient.** 2×12 kW surge = 504 A bank / 252 A per pack — above the 150 A OCP/157 A cell, but **3.5 s ≪ the
	38	300 s OCP delay and < the 300 A SC trip**, so no trip (same logic as Phase 1). Brief, unlike the 18kPV's minutes-long surge.
	39
	40	## D. Out-of-scope gates (flagged, NOT engineered)
	41
	42	14. **NFPA 855 / VT 2025 Fire Code — the biggest non-electrical gate.** 2 packs = 32.2 kWh nameplate; per Swarm §4 likely crosses the
	43	20 kWh residential threshold → detached non-combustible shed ≥ 10 ft, UL 9540 listing or AHJ Hazard Mitigation Analysis, + propane-heater
	44	combustion-air/ventilation/separation. **Pre-clear with VT DPS in writing before ordering the 2nd pack.**
	45	15. **Insurance disclosure (Swarm §7)** — disclose the DIY + non-UL ESS in writing; if excluded, shop Co-op Insurance (Middlebury).
	46	16. **Generator (Phase-1 infrastructure)** — AC-IN to the parallel 6000XP pair (each 50 A passthrough / per the parallel kit), L14-30 inlet + interlock, gen-assist on low SOC.
	47	17. **Battery shed / structure / racking / trenching** — out of scope (owner handles mounting/housing).
	48
	49	## E. Validation status of the safety-critical result
	50
	51	The Path-A string is the **already quadruple-validated Phase-1 7S result** (430.1 V ≤ 480 V): analytic NEC 690.7, pvlib CEC single-diode,
	52	**vocmax**, and an independent adversarial agent. Replicated ×4 across the four MPPTs (2 per 6000XP); no 8S anywhere, so the 430 V string
	53	sits **50 V below its ceiling** — the most conservative string voltage of either path.

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artifacts/results/01_string_phase2.json +182 -0

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	27	"margin_to_design_V": 58.5,
	28	"margin_to_abs_V": 108.5,
	29	"margin_to_500_V": 108.5,
	30	"layout": [
	31	{
	32	"mppt": 0,
	33	"lengths": [
	34	8,
	35	8
	36	]
	37	},
	38	{
	39	"mppt": 1,
	40	"lengths": [
	41	8
	42	]
	43	},
	44	{
	45	"mppt": 2,
	46	"lengths": [
	47	7
	48	]
	49	}
	50	],
	51	"per_mppt": [
	52	{
	53	"mppt": 1,
	54	"n_parallel": 2,
	55	"n_series": 8,
	56	"lengths": [
	57	8,
	58	8
	59	],
	60	"equal_parallel": true,
	61	"string_cold_voc_V": 491.5,
	62	"string_cold_vmp_V": 429.8,
	63	"string_hot_vmp_V": 296.2,
	64	"combined_imp_A": 26.22,
	65	"usable_a_limit": 25,
	66	"combined_isc_A": 27.74,
	67	"isc_a_limit": 31,
	68	"current_clips_at_mpp": true,
	69	"power_W": 9200,
	70	"checks": {
	71	"voc": true,
	72	"vmp_hi": true,
	73	"vmp_lo": true,
	74	"isc": true,
	75	"equal_parallel": true
	76	}
	77	},
	78	{
	79	"mppt": 2,
	80	"n_parallel": 1,
	81	"n_series": 8,
	82	"lengths": [
	83	8
	84	],
	85	"equal_parallel": true,
	86	"string_cold_voc_V": 491.5,
	87	"string_cold_vmp_V": 429.8,
	88	"string_hot_vmp_V": 296.2,
	89	"combined_imp_A": 13.11,
	90	"usable_a_limit": 15,
	91	"combined_isc_A": 13.87,
	92	"isc_a_limit": 19,
	93	"current_clips_at_mpp": false,
	94	"power_W": 4600,
	95	"checks": {
	96	"voc": true,
	97	"vmp_hi": true,
	98	"vmp_lo": true,
	99	"isc": true,
	100	"equal_parallel": true
	101	}
	102	},
	103	{
	104	"mppt": 3,
	105	"n_parallel": 1,
	106	"n_series": 7,
	107	"lengths": [
	108	7
	109	],
	110	"equal_parallel": true,
	111	"string_cold_voc_V": 430.1,
	112	"string_cold_vmp_V": 376.1,
	113	"string_hot_vmp_V": 259.2,
	114	"combined_imp_A": 13.11,
	115	"usable_a_limit": 15,
	116	"combined_isc_A": 13.87,
	117	"isc_a_limit": 19,
	118	"current_clips_at_mpp": false,
	119	"power_W": 4025,
	120	"checks": {
	121	"voc": true,
	122	"vmp_hi": true,
	123	"vmp_lo": true,
	124	"isc": true,
	125	"equal_parallel": true
	126	}
	127	}
	128	],
	129	"any_current_clip": true,
	130	"verdict": "PASS",
	131	"sweep": [
	132	{
	133	"N": 4,
	134	"voc_cold_string_V": 245.8,
	135	"le_design": true,
	136	"le_abs": true,
	137	"margin_to_design_V": 304.2
	138	},
	139	{
	140	"N": 5,
	141	"voc_cold_string_V": 307.2,
	142	"le_design": true,
	143	"le_abs": true,
	144	"margin_to_design_V": 242.8
	145	},
	146	{
	147	"N": 6,
	148	"voc_cold_string_V": 368.6,
	149	"le_design": true,
	150	"le_abs": true,
	151	"margin_to_design_V": 181.4
	152	},
	153	{
	154	"N": 7,
	155	"voc_cold_string_V": 430.1,
	156	"le_design": true,
	157	"le_abs": true,
	158	"margin_to_design_V": 119.9
	159	},
	160	{
	161	"N": 8,
	162	"voc_cold_string_V": 491.5,
	163	"le_design": true,
	164	"le_abs": true,
	165	"margin_to_design_V": 58.5
	166	},
	167	{
	168	"N": 9,
	169	"voc_cold_string_V": 553.0,
	170	"le_design": false,
	171	"le_abs": true,
	172	"margin_to_design_V": -3.0
	173	},
	174	{
	175	"N": 10,
	176	"voc_cold_string_V": 614.4,
	177	"le_design": false,
	178	"le_abs": false,
	179	"margin_to_design_V": -64.4
	180	}
	181	]
	182	}

artifacts/results/01b_vocmax.json +15 -0

…	…	@@ -0,0 +1,15 @@
	1	{
	2	"phase": "phase1",
	3	"vocmax_version": "1.0.1",
	4	"voc_module_stc_V": 52.3,
	5	"voc_module_cold_V": 61.14,
	6	"tmin_C": -40,
	7	"design_ceiling_V": 480,
	8	"abs_ceiling_V": 500,
	9	"string_series_checked": 7,
	10	"string_cold_voc_V": 428.0,
	11	"max_series_le_design": 7,
	12	"max_series_le_abs": 8,
	13	"verdict": "7S PASS",
	14	"note": "offline full-sun Sandia Voc (=linear 690.7); NSRDB statistical run needs NREL key"
	15	}

artifacts/results/01b_vocmax_phase2.json +15 -0

…	…	@@ -0,0 +1,15 @@
	1	{
	2	"phase": "phase2",
	3	"vocmax_version": "1.0.1",
	4	"voc_module_stc_V": 52.3,
	5	"voc_module_cold_V": 61.14,
	6	"tmin_C": -40,
	7	"design_ceiling_V": 550,
	8	"abs_ceiling_V": 600,
	9	"string_series_checked": 8,
	10	"string_cold_voc_V": 489.1,
	11	"max_series_le_design": 8,
	12	"max_series_le_abs": 9,
	13	"verdict": "8S PASS",
	14	"note": "offline full-sun Sandia Voc (=linear 690.7); NSRDB statistical run needs NREL key"
	15	}

artifacts/results/02_production.json +27 -0

…	…	@@ -0,0 +1,27 @@
	1	{
	2	"status": "ok",
	3	"verified_host": "https://developer.nlr.gov",
	4	"system_kw": 8.05,
	5	"ac_annual_kwh": 9622,
	6	"capacity_factor_pct": 13.6454072357225,
	7	"ac_monthly_kwh": [
	8	754,
	9	749,
	10	1015,
	11	895,
	12	883,
	13	830,
	14	910,
	15	916,
	16	896,
	17	710,
	18	577,
	19	487
	20	],
	21	"dec_kwh_day": 15.7,
	22	"jan_kwh_day": 24.3,
	23	"jun_kwh_day": 27.7,
	24	"string_dc_W": 4025,
	25	"array_dc_W": 8050,
	26	"dc_ac_ratio": 1.34
	27	}

artifacts/results/03_conductors.json +80 -0

…	…	@@ -0,0 +1,80 @@
	1	{
	2	"pv_string": {
	3	"run": "PV string (array->inverter, per MPPT)",
	4	"mode": "pv",
	5	"length_ft": 200,
	6	"vref_V": 307.0,
	7	"current_A": 13.11,
	8	"req_ampacity_term_A": 21.7,
	9	"req_ampacity_derated_A": 17.3,
	10	"ambient_C": 40,
	11	"ccc": 4,
	12	"temp_factor90": 0.91,
	13	"fill_factor": 0.8,
	14	"ampacity_gauge": "12",
	15	"ampacity_75C_A": 25,
	16	"ampacity_derated90_A": 21.8,
	17	"final_gauge_AWG": "8",
	18	"gauge_driver": "voltage-drop",
	19	"vdrop_pct": 1.329,
	20	"vdrop_V": 4.08,
	21	"target_pct": 2.0,
	22	"ocpd_A": null,
	23	"ocpd_note": "n/a",
	24	"egc_AWG": null,
	25	"vdrop_sweep_pct": {
	26	"150": 0.997,
	27	"200": 1.329,
	28	"250": 1.661
	29	}
	30	},
	31	"battery": {
	32	"run": "Battery <-> inverter",
	33	"mode": "continuous",
	34	"length_ft": 10,
	35	"vref_V": 51.2,
	36	"current_A": 126.01,
	37	"req_ampacity_term_A": 157.5,
	38	"req_ampacity_derated_A": 157.5,
	39	"ambient_C": 30,
	40	"ccc": 2,
	41	"temp_factor90": 1.0,
	42	"fill_factor": 1.0,
	43	"ampacity_gauge": "2/0",
	44	"ampacity_75C_A": 175,
	45	"ampacity_derated90_A": 195.0,
	46	"final_gauge_AWG": "2/0",
	47	"gauge_driver": "ampacity",
	48	"vdrop_pct": 0.476,
	49	"vdrop_V": 0.244,
	50	"target_pct": 1.0,
	51	"ocpd_A": 175,
	52	"ocpd_note": "OK",
	53	"egc_AWG": "6",
	54	"recommended_upsize_AWG": "4/0"
	55	},
	56	"ac_output": {
	57	"run": "AC output (inverter->main panel)",
	58	"mode": "continuous",
	59	"length_ft": 10,
	60	"vref_V": 240.0,
	61	"current_A": 25.0,
	62	"req_ampacity_term_A": 31.2,
	63	"req_ampacity_derated_A": 31.2,
	64	"ambient_C": 30,
	65	"ccc": 2,
	66	"temp_factor90": 1.0,
	67	"fill_factor": 1.0,
	68	"ampacity_gauge": "10",
	69	"ampacity_75C_A": 35,
	70	"ampacity_derated90_A": 40.0,
	71	"final_gauge_AWG": "8",
	72	"gauge_driver": "240.4(D) OCPD",
	73	"vdrop_pct": 0.162,
	74	"vdrop_V": 0.389,
	75	"target_pct": 2.0,
	76	"ocpd_A": 35,
	77	"ocpd_note": "OK",
	78	"egc_AWG": "10"
	79	}
	80	}

artifacts/results/03_conductors_phase2.json +113 -0

…	…	@@ -0,0 +1,113 @@
	1	{
	2	"pv_string": {
	3	"run": "PV string (array->18kPV input, per string)",
	4	"mode": "pv",
	5	"length_ft": 200,
	6	"vref_V": 307.0,
	7	"current_A": 13.11,
	8	"req_ampacity_term_A": 21.7,
	9	"req_ampacity_derated_A": 17.3,
	10	"ambient_C": 40,
	11	"ccc": 8,
	12	"temp_factor90": 0.91,
	13	"fill_factor": 0.7,
	14	"ampacity_gauge": "12",
	15	"ampacity_75C_A": 25,
	16	"ampacity_derated90_A": 19.1,
	17	"final_gauge_AWG": "8",
	18	"gauge_driver": "voltage-drop",
	19	"vdrop_pct": 1.329,
	20	"vdrop_V": 4.08,
	21	"target_pct": 2.0,
	22	"ocpd_A": null,
	23	"ocpd_note": "n/a",
	24	"egc_AWG": null,
	25	"vdrop_sweep_pct": {
	26	"150": 0.997,
	27	"200": 1.329,
	28	"250": 1.661
	29	},
	30	"n_strings": 4,
	31	"source_fuse_required": false,
	32	"parallel_backfeed_A": 17.3
	33	},
	34	"ac_output": {
	35	"run": "AC output (18kPV->main panel)",
	36	"mode": "continuous",
	37	"length_ft": 10,
	38	"vref_V": 240.0,
	39	"current_A": 50,
	40	"req_ampacity_term_A": 62.5,
	41	"req_ampacity_derated_A": 62.5,
	42	"ambient_C": 30,
	43	"ccc": 2,
	44	"temp_factor90": 1.0,
	45	"fill_factor": 1.0,
	46	"ampacity_gauge": "6",
	47	"ampacity_75C_A": 65,
	48	"ampacity_derated90_A": 75.0,
	49	"final_gauge_AWG": "4",
	50	"gauge_driver": "240.4(D) OCPD",
	51	"vdrop_pct": 0.128,
	52	"vdrop_V": 0.308,
	53	"target_pct": 2.0,
	54	"ocpd_A": 70,
	55	"ocpd_note": "OK",
	56	"egc_AWG": "8"
	57	},
	58	"battery_per_pack": {
	59	"run": "Battery per-pack (pack->busbar)",
	60	"mode": "continuous",
	61	"length_ft": 5,
	62	"vref_V": 51.2,
	63	"current_A": 124.67,
	64	"req_ampacity_term_A": 155.8,
	65	"req_ampacity_derated_A": 155.8,
	66	"ambient_C": 30,
	67	"ccc": 2,
	68	"temp_factor90": 1.0,
	69	"fill_factor": 1.0,
	70	"ampacity_gauge": "2/0",
	71	"ampacity_75C_A": 175,
	72	"ampacity_derated90_A": 195.0,
	73	"final_gauge_AWG": "2/0",
	74	"gauge_driver": "ampacity",
	75	"vdrop_pct": 0.235,
	76	"vdrop_V": 0.121,
	77	"target_pct": 1.0,
	78	"ocpd_A": 175,
	79	"ocpd_note": "OK",
	80	"egc_AWG": "6",
	81	"count": 2
	82	},
	83	"battery_bank": {
	84	"run": "Battery bank (busbar->18kPV)",
	85	"mode": "continuous",
	86	"length_ft": 10,
	87	"vref_V": 51.2,
	88	"current_A": 249.34,
	89	"req_ampacity_term_A": 311.7,
	90	"req_ampacity_derated_A": 311.7,
	91	"ambient_C": 30,
	92	"ccc": 2,
	93	"temp_factor90": 1.0,
	94	"fill_factor": 1.0,
	95	"ampacity_gauge": "400",
	96	"ampacity_75C_A": 335,
	97	"ampacity_derated90_A": 380.0,
	98	"final_gauge_AWG": "400",
	99	"gauge_driver": "ampacity",
	100	"vdrop_pct": 0.313,
	101	"vdrop_V": 0.16,
	102	"target_pct": 1.0,
	103	"ocpd_A": null,
	104	"ocpd_note": "n/a",
	105	"egc_AWG": null,
	106	"req_continuous_A": 311.7,
	107	"parallel_alt": {
	108	"2x2/0_A": 350,
	109	"2x4/0_A": 460,
	110	"single_min": "400"
	111	}
	112	}
	113	}

artifacts/results/04_battery.json +26 -0

…	…	@@ -0,0 +1,26 @@
	1	{
	2	"discharge_A_6kW": 126.0,
	3	"limits_A": {
	4	"inverter max discharge": 140,
	5	"JK-BMS OCP trip (300s)": 150,
	6	"EVE cell-honest (0.5P)": 157,
	7	"JK-BMS marketed max": 200
	8	},
	9	"binding_limit": {
	10	"name": "inverter max discharge",
	11	"A": 140,
	12	"headroom_A": 14.0
	13	},
	14	"discharge_C": 0.401,
	15	"charge_C_pv": 0.398,
	16	"surge_A": 252.0,
	17	"surge_note": "transient only; one pack cannot sustain >6kW continuously \u2014 Phase-2 second pack relieves surge headroom",
	18	"runtime_full_h": 2.68,
	19	"runtime_full_80dod_h": 2.14,
	20	"runtime_1p5kw_80dod_h": 8.6,
	21	"classT_fuse_A": 175,
	22	"cable_AWG": "2/0",
	23	"cable_ampacity_A": 175,
	24	"fuse_cable_ok": true,
	25	"verdict": "PASS"
	26	}

artifacts/results/04_battery_phase2.json +40 -0

…	…	@@ -0,0 +1,40 @@
	1	{
	2	"phase": "phase2",
	3	"pack_count": 2,
	4	"bank_discharge_A_12kW": 249.3,
	5	"bank_demand_A": 249.3,
	6	"per_pack_discharge_A": 124.7,
	7	"bank_limit": {
	8	"name": "inverter max discharge",
	9	"A": 250,
	10	"headroom_A": 0.7
	11	},
	12	"per_pack_limits_A": {
	13	"JK-BMS OCP trip (300s)": 150,
	14	"EVE cell-honest (0.5P)": 157,
	15	"JK-BMS marketed max": 200
	16	},
	17	"per_pack_binding": {
	18	"name": "JK-BMS OCP trip (300s)",
	19	"A": 150,
	20	"headroom_A": 25.3
	21	},
	22	"per_pack_discharge_C": 0.397,
	23	"per_pack_charge_C": 0.398,
	24	"surge_bank_A": 280.5,
	25	"surge_per_pack_A": 140.3,
	26	"surge_note": "2-pack split keeps per-pack surge 140A under the 150A/300s BMS OCP even over the 18kPV's 10-min peak window (the single-pack Phase-1 case relied on the 3.5s 6000XP surge being too brief).",
	27	"bank_usable_kwh": 32.16,
	28	"bank_usable_kwh_80dod": 25.73,
	29	"runtime_12kw_80dod_h": 2.14,
	30	"days_at_avg_load": 0.77,
	31	"days_at_aug_peak": 0.48,
	32	"per_pack_classT_fuse_A": 175,
	33	"per_pack_cable_AWG": "2/0",
	34	"per_pack_cable_ampacity_A": 175,
	35	"bank_aggregate_fuse_A": 350,
	36	"bank_cable_single_AWG": "400",
	37	"fuse_cable_ok": true,
	38	"verdict": "PASS",
	39	"comms_note": "2 packs: JK-BMS master/slave, one master -> 18kPV via CAN (single link). 18kPV native closed-loop is EG4-48V; Docan/JK via a CAN profile \u2014 confirm on arrival. Open-loop fallback fully viable (no battery-life penalty)."
	40	}

artifacts/results/05_checklist.json +131 -0

…	…	@@ -0,0 +1,131 @@
	1	{
	2	"nec_cycle": "2023",
	3	"checks": [
	4	{
	5	"section": "690.7",
	6	"topic": "Max system voltage (cold Voc)",
	7	"status": "PASS",
	8	"evidence": "7S cold Voc 430.1 V <= 480 V design / 500 V abs (margin 69.9 V). Tmin -40C; analytic+pvlib agree."
	9	},
	10	{
	11	"section": "690.8(A)",
	12	"topic": "Max circuit current (Isc x 1.25)",
	13	"status": "PASS",
	14	"evidence": "PV source max current 17.3 A (Isc 13.87 x 1.25)."
	15	},
	16	{
	17	"section": "690.8(B)",
	18	"topic": "Conductor ampacity after 310.15 derates",
	19	"status": "PASS",
	20	"evidence": "PV string 8 Cu: 75C 25A, derated 21.8A >= req 17.3A."
	21	},
	22	{
	23	"section": "690.9 / 690.9(A) Ex",
	24	"topic": "PV source overcurrent (string fusing)",
	25	"status": "PASS",
	26	"evidence": "Not required: 1 string per MPPT (no parallel strings), so no source-circuit fault current can exceed module 30A series-fuse rating. Each MPPT isolated."
	27	},
	28	{
	29	"section": "690.9 / 240 / 480.9",
	30	"topic": "Battery overcurrent (Class-T)",
	31	"status": "PASS",
	32	"evidence": "175A Class-T (DC, 20kAIC) >= 125%x126.0A; <= cable 2/0 ampacity 175A."
	33	},
	34	{
	35	"section": "690.9 / 710.15",
	36	"topic": "Inverter AC output overcurrent",
	37	"status": "PASS",
	38	"evidence": "35A 2-pole >= 125% x 25.0A; protects 8 Cu (240.4(D))."
	39	},
	40	{
	41	"section": "690.12",
	42	"topic": "Rapid shutdown",
	43	"status": "VERIFY-AHJ",
	44	"evidence": "Ground-mounted array NOT on a building: 690.12 (NEC 2023) applies to PV on/in buildings. 6000XP has a built-in RSD initiator if AHJ requires it for conductors entering the dwelling. Confirm AHJ stance for the detached ground-mount."
	45	},
	46	{
	47	"section": "690.13",
	48	"topic": "PV disconnecting means",
	49	"status": "PASS",
	50	"evidence": "6000XP integrated DC switch per MPPT; add an external load-break PV/DC disconnect at the inverter for service isolation."
	51	},
	52	{
	53	"section": "690.15",
	54	"topic": "Disconnect for equipment",
	55	"status": "PASS",
	56	"evidence": "Battery disconnect (switch or the Class-T fused disconnect) within sight of inverter."
	57	},
	58	{
	59	"section": "690.11 / 690.41",
	60	"topic": "DC arc-fault + system grounding (GFDI)",
	61	"status": "PASS",
	62	"evidence": "6000XP integrated PV AFCI (690.11) and PV ground-fault/isolation protection (690.41/690.5)."
	63	},
	64	{
	65	"section": "690.43",
	66	"topic": "Equipment grounding & bonding",
	67	"status": "PASS",
	68	"evidence": "EGCs: PV 10 / battery 6 / AC 10 AWG Cu; bond array frames + all enclosures."
	69	},
	70	{
	71	"section": "690.45",
	72	"topic": "Size of EGC (250.122)",
	73	"status": "PASS",
	74	"evidence": "Battery EGC 6 AWG (OCPD 175A); AC EGC 10 AWG (OCPD 35A); PV EGC min 10 AWG (no source OCPD)."
	75	},
	76	{
	77	"section": "690.47",
	78	"topic": "Grounding electrode (array + DC)",
	79	"status": "ACTION",
	80	"evidence": "Ground-mount: drive an array grounding electrode (rod) and bond per 690.47(A); min 6 AWG Cu GEC, common with the dwelling grounding electrode system."
	81	},
	82	{
	83	"section": "690.31",
	84	"topic": "Wiring methods",
	85	"status": "PASS",
	86	"evidence": "PV in conduit (Sched-40 PVC, squirrel/UV protection per Swarm \u00a716); 8 Cu PV wire/THWN-2 90C."
	87	},
	88	{
	89	"section": "706.30 / 480.7",
	90	"topic": "ESS disconnecting means",
	91	"status": "PASS",
	92	"evidence": "Battery disconnect + Class-T fuse; lockable; within sight of the ESS."
	93	},
	94	{
	95	"section": "706.31 / 480.9",
	96	"topic": "ESS overcurrent protection",
	97	"status": "PASS",
	98	"evidence": "175A Class-T at the battery positive, interrupt 20kAIC > pack fault current."
	99	},
	100	{
	101	"section": "710.15",
	102	"topic": "Stand-alone system output",
	103	"status": "PASS",
	104	"evidence": "6000XP 6kW 120/240 split-phase; output 25.0A; no utility backfeed (off-grid)."
	105	},
	106	{
	107	"section": "705",
	108	"topic": "Interconnection (120% / backfeed)",
	109	"status": "N/A",
	110	"evidence": "Off-grid, no utility interconnection. Main panel subfed with main breaker locked off (Swarm \u00a717)."
	111	},
	112	{
	113	"section": "690.53/690.54/690.56/110.21",
	114	"topic": "Labels & placards",
	115	"status": "ACTION",
	116	"evidence": "Required: max system voltage (690.53), inverter output rating (690.54), rapid-shutdown placard if applicable (690.56(C)), DC disconnect & directory, battery hazard label. Generate per the computed ratings."
	117	},
	118	{
	119	"section": "Voltage drop (design target)",
	120	"topic": "DC<=2% / batt<=1% / AC<=2%",
	121	"status": "PASS",
	122	"evidence": "DC 1.329% (150-250ft: {'150': 0.997, '200': 1.329, '250': 1.661}); battery 0.476%; AC 0.162%. (Informational; not NEC-mandated.)"
	123	}
	124	],
	125	"summary": {
	126	"PASS": 16,
	127	"VERIFY-AHJ": 1,
	128	"ACTION": 2,
	129	"N/A": 1
	130	}
	131	}

artifacts/results/05_checklist_phase2.json +146 -0

…	…	@@ -0,0 +1,146 @@
	1	{
	2	"phase": "phase2",
	3	"nec_cycle": "2023",
	4	"checks": [
	5	{
	6	"section": "690.7",
	7	"topic": "Max system voltage (cold Voc)",
	8	"status": "PASS",
	9	"evidence": "Longest string 8S cold Voc 491.5 V <= 550 V MPPT-fault / 600 V abs (margin 58.5 V to fault, 108.5 V to abs). Tmin -40C; analytic+pvlib+vocmax+independent agent agree. 9S=553V REJECTED (>550)."
	10	},
	11	{
	12	"section": "690.8(A)",
	13	"topic": "Max circuit current",
	14	"status": "PASS",
	15	"evidence": "Per string Isc x1.25 = 17.3 A (each string a dedicated homerun). MPPT1 internally combines 2 strings = 27.7 A actual <= 31 A MPPT1 Isc rating; MPPT2/3 single string <= 19 A."
	16	},
	17	{
	18	"section": "690.8(B)",
	19	"topic": "Conductor ampacity after 310.15 derates",
	20	"status": "PASS",
	21	"evidence": "PV 8Cu derated 19.1A >= 17.3A (8 CCC, 0.70 fill); AC 4Cu; per-pack 2/0Cu; bank 400kcmil (or 2x2/0 / 2x4/0)."
	22	},
	23	{
	24	"section": "690.9 / 690.9(A) Ex",
	25	"topic": "PV source-circuit overcurrent (fusing)",
	26	"status": "PASS",
	27	"evidence": "NOT required: MPPT1 parallels only 2 strings -> max backfeed 1.25xIsc=17.3A <= module 30A series fuse (3+ parallel strings would require fuses). MPPT2/3 single string. No combiner."
	28	},
	29	{
	30	"section": "690.9 / 240 / 480.9",
	31	"topic": "Battery overcurrent (per-pack Class-T)",
	32	"status": "PASS",
	33	"evidence": "2x 175A Class-T (DC, 20kAIC), one per pack, >= 125% x 124.7A/pack; <= 2/0 cable 175A. Bank aggregate 350A coordinated with the bank conductor."
	34	},
	35	{
	36	"section": "690.9 / 710.15",
	37	"topic": "Inverter AC output overcurrent",
	38	"status": "PASS",
	39	"evidence": "70A 2-pole >= 125% x 50A; protects 4Cu (240.4(D)); EGC 8AWG."
	40	},
	41	{
	42	"section": "690.11",
	43	"topic": "DC arc-fault (AFCI)",
	44	"status": "PASS",
	45	"evidence": "EG4 18kPV integrated PV AFCI (690.11 / UL1699B, per datasheet)."
	46	},
	47	{
	48	"section": "690.12",
	49	"topic": "Rapid shutdown",
	50	"status": "VERIFY-AHJ",
	51	"evidence": "18kPV has an integrated RSD initiator (datasheet cites NEC 2020:690.12). Detached ground-mount (not on a building) is likely exempt, but PV/DC conductors enter the dwelling -> confirm the VT DPS inspector's stance for NEC 2023. Initiator present if required."
	52	},
	53	{
	54	"section": "690.13 / 690.15",
	55	"topic": "PV + equipment disconnects",
	56	"status": "PASS",
	57	"evidence": "18kPV integrated PV disconnect; add an external load-break DC/PV disconnect for service. Battery: 2 per-pack disconnects + a 249A-class bank disconnect within sight of the inverter."
	58	},
	59	{
	60	"section": "690.41(B)",
	61	"topic": "System grounding / GFDI",
	62	"status": "PASS",
	63	"evidence": "18kPV integrated PV ground-fault monitoring (690.41(B)) + pole-sensitive leakage-current monitor + integrated SPD (per datasheet)."
	64	},
	65	{
	66	"section": "690.43 / 690.45",
	67	"topic": "Equipment grounding & EGC size (250.122)",
	68	"status": "PASS",
	69	"evidence": "EGCs: PV 10AWG (no source OCPD), per-pack 6AWG (175A), AC 8AWG (70A), bank 4AWG (sized to disconnect). Bond all array frames + enclosures + the battery busbar."
	70	},
	71	{
	72	"section": "690.47",
	73	"topic": "Grounding electrode (array + DC)",
	74	"status": "ACTION",
	75	"evidence": "Ground-mount: drive an array grounding electrode (rod), 6AWG Cu GEC bonded to the dwelling GES (690.47(A)). Carries forward from Phase 1; verify for the expanded array footprint."
	76	},
	77	{
	78	"section": "690.31",
	79	"topic": "Wiring methods",
	80	"status": "PASS",
	81	"evidence": "PV in Sched-40 PVC conduit (squirrel/UV, Swarm \u00a716); 8Cu THWN-2/PV 90C. 4 strings -> split across 2 conduits to relax the 8-CCC fill."
	82	},
	83	{
	84	"section": "705",
	85	"topic": "Interconnection (utility)",
	86	"status": "N/A",
	87	"evidence": "Off-grid, no utility interconnection (no 705.12 backfeed limit). Generator AC-IN to the 18kPV (200A AC bypass / 90A gen) with the main panel subfed and its main breaker locked off (Swarm \u00a717); transfer is internal to the hybrid inverter."
	88	},
	89	{
	90	"section": "706.7 / 706.20",
	91	"topic": "ESS \u2014 multi-pack arrangement & control",
	92	"status": "PASS",
	93	"evidence": "2x Docan S3 (LFP, JK-PB2A16S20P BMS) in parallel on a DC busbar. Each pack has its own BMS + Class-T + disconnect. Bank discharge 249A split 124.7A/pack \u2014 within the 150A/300s JK OCP (17% headroom) and the 157A EVE-cell limit. C-rate 0.397C."
	94	},
	95	{
	96	"section": "706.30 / 480.7",
	97	"topic": "ESS disconnecting means",
	98	"status": "PASS",
	99	"evidence": "Per-pack disconnects + a bank disconnect (lockable, within sight of the ESS); the 18kPV battery port is the inverter-side disconnect. BMS opens on cell-level faults."
	100	},
	101	{
	102	"section": "706.31 / 480.9",
	103	"topic": "ESS overcurrent protection",
	104	"status": "PASS",
	105	"evidence": "Per-pack 175A Class-T (20kAIC > pack prospective fault). Layered: JK-BMS (150A/300s OCP, 300A SC) protects cells; Class-T protects each pack cable."
	106	},
	107	{
	108	"section": "706.x / BMS comms",
	109	"topic": "Multi-pack BMS communications",
	110	"status": "VERIFY",
	111	"evidence": "2 packs: JK-BMS master/slave, one master -> 18kPV via CAN (a SINGLE comms link, vs 2 for a parallel-6000XP path). 18kPV native closed-loop is EG4-48V; the Docan/JK pack runs via a CAN profile -> confirm on arrival. Open-loop fallback fully viable (no battery-life penalty)."
	112	},
	113	{
	114	"section": "710.15",
	115	"topic": "Stand-alone system output",
	116	"status": "PASS",
	117	"evidence": "18kPV 12kW 120/240V split-phase, output 50A; off-grid, no utility backfeed. Continuous line 8000W/120V leg covers the household peak; surge 13.5kW (w/o PV)."
	118	},
	119	{
	120	"section": "690.53/54/56 / 110.21",
	121	"topic": "Labels & placards",
	122	"status": "ACTION",
	123	"evidence": "Max system voltage 491.5V (690.53), inverter output 12kW/50A (690.54), RSD placard if AHJ requires (690.56(C)), DC disconnect + directory, per-pack battery hazard labels. Generate from these computed ratings."
	124	},
	125	{
	126	"section": "NFPA 855 / VT 2025 Fire Code",
	127	"topic": "ESS fire code (OUT OF SCOPE \u2014 GATE)",
	128	"status": "FLAG",
	129	"evidence": "2 packs = 32.2kWh nameplate. Swarm \u00a74: even 2 packs (32kWh) likely crosses the 20kWh residential threshold (3 packs/48kWh definitively) -> detached non-combustible shed >=10ft, UL9540 listing or AHJ hazard-mitigation analysis, + propane-heater combustion-air/ventilation/separation. NOT engineered here \u2014 pre-clear with VT DPS in writing before ordering the 2nd pack."
	130	},
	131	{
	132	"section": "Voltage drop (design target)",
	133	"topic": "DC<=2% / batt<=1% / AC<=2%",
	134	"status": "PASS",
	135	"evidence": "DC 1.329% (150-250ft: {'150': 0.997, '200': 1.329, '250': 1.661}); per-pack 0.235%; bank 0.313%; AC 0.128%. (Informational; not NEC-mandated.)"
	136	}
	137	],
	138	"summary": {
	139	"PASS": 16,
	140	"VERIFY-AHJ": 1,
	141	"ACTION": 2,
	142	"N/A": 1,
	143	"VERIFY": 1,
	144	"FLAG": 1
	145	}
	146	}

artifacts/results/07_load_capacity.json +67 -0

…	…	@@ -0,0 +1,67 @@
	1	{
	2	"production_kwh_day": {
	3	"Deep winter (Dec)": 15.7,
	4	"Winter avg (Dec-Jan)": 20.0,
	5	"Shoulder (Mar/Apr/Sep/Oct)": 28.8,
	6	"Summer (Jun)": 27.7,
	7	"Annual avg": 26.4
	8	},
	9	"usage_band": [
	10	0.85,
	11	0.95
	12	],
	13	"supportable_daily_load_kwh": [
	14	{
	15	"season": "Deep winter (Dec)",
	16	"ac_kwh_day": 15.7,
	17	"supportable_kwh_day": [
	18	13,
	19	15
	20	]
	21	},
	22	{
	23	"season": "Winter avg (Dec-Jan)",
	24	"ac_kwh_day": 20.0,
	25	"supportable_kwh_day": [
	26	17,
	27	19
	28	]
	29	},
	30	{
	31	"season": "Shoulder (Mar/Apr/Sep/Oct)",
	32	"ac_kwh_day": 28.8,
	33	"supportable_kwh_day": [
	34	24,
	35	27
	36	]
	37	},
	38	{
	39	"season": "Summer (Jun)",
	40	"ac_kwh_day": 27.7,
	41	"supportable_kwh_day": [
	42	24,
	43	26
	44	]
	45	},
	46	{
	47	"season": "Annual avg",
	48	"ac_kwh_day": 26.4,
	49	"supportable_kwh_day": [
	50	22,
	51	25
	52	]
	53	}
	54	],
	55	"inverter_continuous_W": 6000,
	56	"inverter_surge_W": 12000,
	57	"per_leg_A": 25,
	58	"battery_usable_kwh_80dod": 12.9,
	59	"days_autonomy": {
	60	"5": 2.58,
	61	"8": 1.61,
	62	"10": 1.29,
	63	"13": 0.99,
	64	"20": 0.65
	65	},
	66	"note": "capacity envelope, not a load study; generator backfills winter deficit"
	67	}

artifacts/results/08_load_actual.json +59 -0

…	…	@@ -0,0 +1,59 @@
	1	{
	2	"source": "data/hardwick_usage.csv",
	3	"last12_kwh_yr": 12237,
	4	"monthly_avg_kwh": 1020,
	5	"daily_avg_kwh": 33.5,
	6	"min_month_kwh": 744,
	7	"max_month_kwh": 1677,
	8	"seasonal_daily_kwh": {
	9	"winter": 26.6,
	10	"shoulder": 31.9,
	11	"summer": 43.4
	12	},
	13	"august_peak_kwh_day": 54.1,
	14	"vs_supportable": {
	15	"winter": {
	16	"actual_kwh_day": 26.6,
	17	"supportable": [
	18	17,
	19	19
	20	],
	21	"solar_prod_kwh_day": 20.0,
	22	"solar_covers_pct": 75
	23	},
	24	"shoulder": {
	25	"actual_kwh_day": 31.9,
	26	"supportable": [
	27	24,
	28	27
	29	],
	30	"solar_prod_kwh_day": 28.8,
	31	"solar_covers_pct": 90
	32	},
	33	"summer": {
	34	"actual_kwh_day": 43.4,
	35	"supportable": [
	36	24,
	37	26
	38	],
	39	"solar_prod_kwh_day": 27.7,
	40	"solar_covers_pct": 64
	41	},
	42	"August": {
	43	"actual_kwh_day": 54.1,
	44	"supportable": [
	45	24,
	46	26
	47	],
	48	"solar_prod_kwh_day": 27.7,
	49	"solar_covers_pct": 51
	50	}
	51	},
	52	"annual_production_kwh": 9622,
	53	"array_pct_of_load": 79,
	54	"annual_cost_usd": 2778.53,
	55	"weighted_avg_cost_per_kwh": 0.227,
	56	"min_monthly_bill_usd": 170.71,
	57	"max_monthly_bill_usd": 384.45,
	58	"verdict": "Phase-1 (~8 kW / 16 kWh) offsets ~half (Aug) to ~90% (shoulder) of this load by season; full off-grid coverage needs load reduction (propane/shedding) + the Phase-2 PV expansion + 2nd battery. Confirms Swarm 'Phase 2 = more PV'."
	59	}

artifacts/results/09_phase2.json +36 -0

…	…	@@ -0,0 +1,36 @@
	1	{
	2	"remaining_panels": 17,
	3	"kw_full_pallet": 17.82,
	4	"full_pallet_annual_kwh": 20962,
	5	"array_pct_of_load": 171,
	6	"dec_kwh_day": 34.0,
	7	"winter_kwh_day": 43.1,
	8	"summer_kwh_day": 63.9,
	9	"panels_added_cost": 0,
	10	"inverter_parallel_6000xp": 1699,
	11	"inverter_18kpv_swap_net": [
	12	3500,
	13	3700
	14	],
	15	"battery_plus1_pack": [
	16	1758,
	17	2000
	18	],
	19	"battery_plus2_packs": [
	20	3516,
	21	4000
	22	],
	23	"bos": [
	24	800,
	25	1500
	26	],
	27	"bundle_lean_usd": [
	28	4257,
	29	5199
	30	],
	31	"bundle_recommended_usd": [
	32	7816,
	33	9200
	34	],
	35	"note": "panels $0 (owned); cost figures estimates (Swarm \u00a710/Key Decisions); energy computed"
	36	}

artifacts/results/10_compare.json +66 -0

…	…	@@ -0,0 +1,66 @@
	1	{
	2	"path_A": {
	3	"name": "A: 2x EG4 6000XP",
	4	"panels": 28,
	5	"strings": 4,
	6	"series": "4x7S",
	7	"kw": 16.1,
	8	"pv_usable_w": 16000,
	9	"ac_w": 12000,
	10	"batt_lim_a": 280,
	11	"eff": 0.93,
	12	"string_voc": 430.1,
	13	"voc_ceiling": 480,
	14	"mppts": 4,
	15	"units": 2,
	16	"comms_links": 2,
	17	"spares": 3,
	18	"annual": 19213,
	19	"dec": 31.3,
	20	"winter": 39.9,
	21	"summer": 57.7,
	22	"pct_load": 157,
	23	"cov_winter": 128,
	24	"cov_summer": 113,
	25	"cov_aug": 91,
	26	"host": "developer.nlr.gov",
	27	"pv_headroom_w": -100.00000000000182,
	28	"i_bank": 252.0,
	29	"i_pack": 126.0,
	30	"batt_headroom_a": 28.0,
	31	"meets_all_seasons": false
	32	},
	33	"path_B": {
	34	"name": "B: 1x EG4 18kPV",
	35	"panels": 31,
	36	"strings": 4,
	37	"series": "8+8+8+7S",
	38	"kw": 17.82,
	39	"pv_usable_w": 18000,
	40	"ac_w": 12000,
	41	"batt_lim_a": 250,
	42	"eff": 0.94,
	43	"string_voc": 491.5,
	44	"voc_ceiling": 550,
	45	"mppts": 3,
	46	"units": 1,
	47	"comms_links": 1,
	48	"spares": 0,
	49	"annual": 20962,
	50	"dec": 34.0,
	51	"winter": 43.1,
	52	"summer": 63.9,
	53	"pct_load": 171,
	54	"cov_winter": 138,
	55	"cov_summer": 125,
	56	"cov_aug": 100,
	57	"host": "developer.nlr.gov",
	58	"pv_headroom_w": 180.0,
	59	"i_bank": 249.3,
	60	"i_pack": 124.7,
	61	"batt_headroom_a": 0.7,
	62	"meets_all_seasons": true
	63	},
	64	"production_delta_kwh": 1749,
	65	"note": "production/loading computed (PVWatts + datasheet limits); cost is estimate"
	66	}

artifacts/results/11_pathA.json +241 -0

…	…	@@ -0,0 +1,241 @@
	1	{
	2	"meta": {
	3	"path": "A",
	4	"inverters": 2,
	5	"panels": 28,
	6	"spares": 3,
	7	"kw": 16.1,
	8	"strings": 4,
	9	"n_series": 7,
	10	"string_cold_voc_V": 430.1,
	11	"voc_ceiling_V": 480,
	12	"array_dc_W": 16100,
	13	"pv_usable_W": 16000
	14	},
	15	"pv_string": {
	16	"run": "PV string (array->6000XP MPPT, per string)",
	17	"mode": "pv",
	18	"length_ft": 200,
	19	"vref_V": 307.0,
	20	"current_A": 13.11,
	21	"req_ampacity_term_A": 21.7,
	22	"req_ampacity_derated_A": 17.3,
	23	"ambient_C": 40,
	24	"ccc": 8,
	25	"temp_factor90": 0.91,
	26	"fill_factor": 0.7,
	27	"ampacity_gauge": "12",
	28	"ampacity_75C_A": 25,
	29	"ampacity_derated90_A": 19.1,
	30	"final_gauge_AWG": "8",
	31	"gauge_driver": "voltage-drop",
	32	"vdrop_pct": 1.329,
	33	"vdrop_V": 4.08,
	34	"target_pct": 2.0,
	35	"ocpd_A": null,
	36	"ocpd_note": "n/a",
	37	"egc_AWG": null,
	38	"vdrop_sweep_pct": {
	39	"150": 0.997,
	40	"200": 1.329,
	41	"250": 1.661
	42	},
	43	"source_fuse_required": false
	44	},
	45	"ac_per_unit": {
	46	"run": "AC per-unit (6000XP->AC combiner)",
	47	"mode": "continuous",
	48	"length_ft": 10,
	49	"vref_V": 240.0,
	50	"current_A": 25,
	51	"req_ampacity_term_A": 31.2,
	52	"req_ampacity_derated_A": 31.2,
	53	"ambient_C": 30,
	54	"ccc": 2,
	55	"temp_factor90": 1.0,
	56	"fill_factor": 1.0,
	57	"ampacity_gauge": "10",
	58	"ampacity_75C_A": 35,
	59	"ampacity_derated90_A": 40.0,
	60	"final_gauge_AWG": "8",
	61	"gauge_driver": "240.4(D) OCPD",
	62	"vdrop_pct": 0.162,
	63	"vdrop_V": 0.389,
	64	"target_pct": 2.0,
	65	"ocpd_A": 35,
	66	"ocpd_note": "OK",
	67	"egc_AWG": "10"
	68	},
	69	"ac_combined": {
	70	"run": "AC combined (busbar->main panel)",
	71	"mode": "continuous",
	72	"length_ft": 10,
	73	"vref_V": 240.0,
	74	"current_A": 50,
	75	"req_ampacity_term_A": 62.5,
	76	"req_ampacity_derated_A": 62.5,
	77	"ambient_C": 30,
	78	"ccc": 2,
	79	"temp_factor90": 1.0,
	80	"fill_factor": 1.0,
	81	"ampacity_gauge": "6",
	82	"ampacity_75C_A": 65,
	83	"ampacity_derated90_A": 75.0,
	84	"final_gauge_AWG": "4",
	85	"gauge_driver": "240.4(D) OCPD",
	86	"vdrop_pct": 0.128,
	87	"vdrop_V": 0.308,
	88	"target_pct": 2.0,
	89	"ocpd_A": 70,
	90	"ocpd_note": "OK",
	91	"egc_AWG": "8"
	92	},
	93	"battery_per_pack": {
	94	"run": "Battery per-pack (pack->busbar)",
	95	"mode": "continuous",
	96	"length_ft": 5,
	97	"vref_V": 51.2,
	98	"current_A": 126.01,
	99	"req_ampacity_term_A": 157.5,
	100	"req_ampacity_derated_A": 157.5,
	101	"ambient_C": 30,
	102	"ccc": 2,
	103	"temp_factor90": 1.0,
	104	"fill_factor": 1.0,
	105	"ampacity_gauge": "2/0",
	106	"ampacity_75C_A": 175,
	107	"ampacity_derated90_A": 195.0,
	108	"final_gauge_AWG": "2/0",
	109	"gauge_driver": "ampacity",
	110	"vdrop_pct": 0.238,
	111	"vdrop_V": 0.122,
	112	"target_pct": 1.0,
	113	"ocpd_A": 175,
	114	"ocpd_note": "OK",
	115	"egc_AWG": "6"
	116	},
	117	"battery_per_inverter": {
	118	"run": "Battery per-inverter (busbar->6000XP)",
	119	"mode": "continuous",
	120	"length_ft": 10,
	121	"vref_V": 51.2,
	122	"current_A": 126.01,
	123	"req_ampacity_term_A": 157.5,
	124	"req_ampacity_derated_A": 157.5,
	125	"ambient_C": 30,
	126	"ccc": 2,
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	129	"ampacity_gauge": "2/0",
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	131	"ampacity_derated90_A": 195.0,
	132	"final_gauge_AWG": "2/0",
	133	"gauge_driver": "ampacity",
	134	"vdrop_pct": 0.476,
	135	"vdrop_V": 0.244,
	136	"target_pct": 1.0,
	137	"ocpd_A": 175,
	138	"ocpd_note": "OK",
	139	"egc_AWG": "6"
	140	},
	141	"bank": {
	142	"i_bank_A": 252.0,
	143	"i_pack_A": 126.0,
	144	"i_inv_A": 126.0,
	145	"busbar_A": 250
	146	},
	147	"limits": {
	148	"bank_limit_A": 280,
	149	"bank_headroom_A": 28.0,
	150	"per_inv_limit_A": 140,
	151	"per_inv_headroom_A": 14.0,
	152	"per_pack_binding": "JK-BMS OCP (300s)",
	153	"per_pack_binding_A": 150,
	154	"per_pack_headroom_A": 24.0,
	155	"c_dis": 0.401,
	156	"c_chg": 0.398,
	157	"surge_bank_A": 504.0,
	158	"surge_pack_A": 252.0,
	159	"surge_duration_s": 3.5,
	160	"bank_usable_kwh_80dod": 25.73,
	161	"days_avg": 0.77,
	162	"days_peak": 0.48,
	163	"classT_fuse_A": 175,
	164	"classT_count": 4
	165	},
	166	"production": {
	167	"annual_kwh": 19213,
	168	"pct_load": 157,
	169	"cov_winter": 128,
	170	"cov_summer": 113,
	171	"cov_aug": 91,
	172	"meets_all_seasons": false
	173	},
	174	"nec_checks": [
	175	{
	176	"section": "690.7",
	177	"status": "PASS",
	178	"evidence": "Max system voltage 430.1V (7S) <= 480V design / 500V abs (validated x4 strings)."
	179	},
	180	{
	181	"section": "690.8(A)",
	182	"status": "PASS",
	183	"evidence": "Per string Isc x1.25 = 17.3A; 1 string/MPPT -> Isc 13.87A <= 25A MPPT rating, Imp 13.11A <= 17A input."
	184	},
	185	{
	186	"section": "690.9(A) Ex",
	187	"status": "PASS",
	188	"evidence": "NO PV source fusing: exactly 1 string per MPPT (no parallel strings) on either 6000XP."
	189	},
	190	{
	191	"section": "690.9 / 710.15",
	192	"status": "PASS",
	193	"evidence": "AC OCPD: per-unit 35A 2-pole x2 (8AWG) at the parallel busbar; combined 70A (4AWG) to main panel."
	194	},
	195	{
	196	"section": "690.11/690.41(B)",
	197	"status": "PASS",
	198	"evidence": "Each 6000XP has integrated PV AFCI + GFDI/isolation (x2 units)."
	199	},
	200	{
	201	"section": "690.12",
	202	"status": "VERIFY-AHJ",
	203	"evidence": "Each 6000XP supplies an RSD initiator if required; same ground-mount/AHJ question as Phase 1/Path B."
	204	},
	205	{
	206	"section": "690.13/690.15",
	207	"status": "PASS",
	208	"evidence": "Each 6000XP integrated DC disconnect; bank + per-pack + per-inverter disconnects."
	209	},
	210	{
	211	"section": "690.9/480.9/706.31",
	212	"status": "PASS",
	213	"evidence": "4x 175A Class-T (2 packs + 2 inverter inputs), 20kAIC, <= 2/0 cable 175A."
	214	},
	215	{
	216	"section": "705",
	217	"status": "N/A",
	218	"evidence": "Off-grid. Two inverters PARALLELED (EG4 parallel kit), not utility-interactive; main panel subfed, main breaker locked off."
	219	},
	220	{
	221	"section": "706.7",
	222	"status": "PASS",
	223	"evidence": "2-pack bank on a busbar feeding 2 inverters; bank 252A split 126A/pack (17% under 150A BMS) and 126A/inverter (14A under 140A)."
	224	},
	225	{
	226	"section": "706.x comms",
	227	"status": "VERIFY",
	228	"evidence": "TWO JK->Pylontech-CAN links (one per 6000XP) to configure (Swarm \u00a79). Open-loop fallback viable."
	229	},
	230	{
	231	"section": "Redundancy",
	232	"status": "NOTE",
	233	"evidence": "N+1: one 6000XP can keep ~half the system (8kW PV / 6kW AC) running if the other fails."
	234	},
	235	{
	236	"section": "690.53/54/56",
	237	"status": "ACTION",
	238	"evidence": "Labels: max system voltage 430.1V, 2x inverter output ratings, disconnects, battery hazard."
	239	}
	240	]
	241	}

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data/hardwick_usage.csv +32 -0

…	…	@@ -0,0 +1,32 @@
	1	# Hardwick Electric Department — billed electricity usage + cost (saved for reuse in calcs)
	2	# Account 801398-001 · Paul Flint · 423 Main St, Greensboro Bend VT 05842 (NE Kingdom) · Meter 10720
	3	# Source: AccountLedgerPrint.pdf + May-2026 bill mJ2ftoNynkW87jYvC5amBQ10.pdf (owner's Downloads)
	4	# Extracted 2026-06-02. RAW columns from the ledger: net_kwh (billed "Net KWH"; assumed = consumption,
	5	# no on-site generation evident) and bill_amount (billed net cost, USD).
	6	# avg cost/kWh is NOT stored here — it is COMPUTED by common.load_usage() (= bill_amount / net_kwh).
	7	# bill_date = MM/DD/YY (~usage month). Loader skips these '#' lines. Newest first.
	8	bill_date,net_kwh,bill_amount,reading_type
	9	05/15/26,943,216.00,NORMAL
	10	04/15/26,870,199.30,NORMAL
	11	03/15/26,1021,233.85,NORMAL
	12	02/15/26,791,181.23,NORMAL
	13	01/15/26,744,170.71,NORMAL
	14	12/15/25,863,197.97,NORMAL
	15	11/15/25,783,179.65,NORMAL
	16	10/15/25,969,222.26,NORMAL
	17	09/15/25,1260,288.92,NORMAL
	18	08/15/25,1677,384.45,NORMAL
	19	07/15/25,1261,289.15,NORMAL
	20	06/15/25,1055,215.04,NORMAL
	21	05/15/25,800,163.12,NORMAL
	22	04/15/25,690,140.72,NORMAL
	23	03/15/25,675,137.67,NORMAL
	24	02/15/25,747,152.33,NORMAL
	25	01/15/25,774,157.90,NORMAL
	26	12/15/24,863,176.02,NORMAL
	27	11/15/24,774,157.90,NORMAL
	28	10/15/24,847,172.76,NORMAL
	29	09/15/24,877,178.88,NORMAL
	30	08/15/24,1427,290.90,NORMAL
	31	07/15/24,510,104.13,ESTIMATED
	32	06/15/24,605,123.48,NORMAL

requirements.txt +15 -0

…	…	@@ -0,0 +1,15 @@
	1	# PRSM electrical-review grounding stack
	2	# python -m venv .venv && source .venv/bin/activate && pip install -r requirements.txt
	3
	4	nrel-pysam # NREL SAM wrapper: Pvwattsv8 production / per-MPPT energy
	5	pvlib # benchmark PV models: IV curves, cell temp, cross-check
	6	vocmax # NEC 690.7 cold-Voc string sizing from NSRDB extreme temps
	7	schemdraw # electrical schematic rendering (SLD + wiring → PNG/SVG)
	8	matplotlib # schemdraw backend + any supporting plots
	9	requests # PVWatts V8 REST API calls
	10	pandas # tabular conductor/ampacity/voltage-drop calcs
	11	numpy
	12	pyyaml # reads site.yaml (the single source of design inputs)
	13
	14	# Needs a free NREL API key for PVWatts + NSRDB (vocmax):
	15	# export NREL_API_KEY=... (get at developer.nrel.gov — verify host: developer.nlr.gov as of 2026-05-29)

scripts/01_string_sizing.py +423 -0

…	…	@@ -0,0 +1,423 @@
	1	"""01 — PV string sizing. THE binding safety constraint (NEC 690.7).
	2
	3	Max modules-in-series so cold-weather Voc stays under the inverter's PV-voltage
	4	ceiling, AND the operating MPP voltage stays inside the MPPT tracking window.
	5
	6	Three independent methods, must agree:
	7	(A) Analytic NEC 690.7 cold-Voc: Voc(T) = Voc_stc * [1 + beta/100 * (Tmin - 25)]
	8	with Tmin = the lowest expected ambient (NSRDB extreme min if a key is
	9	available, else the documented NEK design low). This is the binding number.
	10	(B) vocmax / NSRDB — pulls the site-specific historical extreme-min air temp
	11	(NEC 690.7's "lowest expected ambient") to refine Tmin in (A).
	12	(C) pvlib De Soto single-diode — independent Voc(Tmin) cross-check, plus the
	13	operating Vmp(T) used for the MPPT-window check.
	14
	15	Run: ~/.venvs/prsm-electrical/bin/python scripts/01_string_sizing.py
	16	Optional: export NREL_API_KEY=... (enables method B; verify host first)
	17	"""
	18	import argparse
	19	import math
	20	import os
	21	from collections import Counter
	22	from common import load_site, require, get, banner, result, dump_result, is_phase2, suffix
	23
	24	DESIGN_HOT_CELL_C = 70.0 # conservative max open-rack cell temp for hot-Vmp >= MPPT min check
	25	K_B = 1.380649e-23 # Boltzmann (J/K)
	26	Q_E = 1.602176634e-19 # elementary charge (C)
	27	DIODE_N = 1.1 # diode ideality for the bifacial Voc adder
	28
	29
	30	def bifacial_voc_adder(cells_series, rear_frac, bifaciality, t_ref_C=25.0, n=DIODE_N):
	31	"""Open-circuit voltage rise from rear-side photocurrent on a bifacial module:
	32	dVoc = Ns * n * (kT/q) * ln(1 + phi_eff), phi_eff = rear_frac * bifaciality.
	33	Evaluated at 25C (conservative-large adder). Adds to the cold-temp Voc."""
	34	vth = K_B * (t_ref_C + 273.15) / Q_E
	35	return cells_series * n * vth * math.log(1.0 + rear_frac * bifaciality)
	36
	37
	38	def analytic_voc(voc_stc, beta_pct_per_C, t_cell_C):
	39	"""NEC 690.7 linear temperature correction. beta in %/C (negative)."""
	40	return voc_stc * (1.0 + (beta_pct_per_C / 100.0) * (t_cell_C - 25.0))
	41
	42
	43	def analytic_v(v_stc, tempco_pct_per_C, t_cell_C):
	44	return v_stc * (1.0 + (tempco_pct_per_C / 100.0) * (t_cell_C - 25.0))
	45
	46
	47	def plan_phase2_strings(modules, max_s, inputs_per_mppt):
	48	"""Distribute `modules` panels into series strings across MPPTs with asymmetric
	49	input counts (e.g. EG4 18kPV = [2,1,1]). Rules:
	50	- total strings <= sum(inputs_per_mppt); each string <= max_s;
	51	- strings PARALLELED on one MPPT must be EQUAL length (matched Vmp tracking);
	52	- use ALL panels, balanced as evenly as the constraints allow.
	53	Greedy: start one string per available input, share the panels evenly (base count),
	54	then add the remainder one panel at a time (longest-first, capped at max_s); finally
	55	assign equal-length groups to multi-input MPPTs first. Returns (plan, lengths) where
	56	plan is a list of {mppt, lengths:[...]} sorted by mppt index."""
	57	total_inputs = sum(inputs_per_mppt)
	58	if modules > total_inputs * max_s:
	59	raise SystemExit(f"[BLOCKED] {modules} panels exceed capacity "
	60	f"{total_inputs} strings x {max_s}S = {total_inputs*max_s}")
	61	base = modules // total_inputs
	62	lengths = [base] * total_inputs
	63	rem = modules - base * total_inputs
	64	i = 0
	65	while rem > 0:
	66	if lengths[i] < max_s:
	67	lengths[i] += 1
	68	rem -= 1
	69	i = (i + 1) % total_inputs
	70	lengths.sort(reverse=True) # e.g. [8,8,8,7]
	71	pool = lengths[:]
	72	plan = []
	73	# multi-input MPPTs first so they can claim an equal-length group
	74	for m in sorted(range(len(inputs_per_mppt)), key=lambda x: -inputs_per_mppt[x]):
	75	k = inputs_per_mppt[m]
	76	if k == 1:
	77	grp = [pool.pop(0)] # take the longest remaining
	78	else:
	79	cnt = Counter(pool)
	80	val = next((v for v in sorted(cnt, reverse=True) if cnt[v] >= k), None)
	81	grp = [val] * k if val is not None else sorted(pool, reverse=True)[:k]
	82	for g in grp:
	83	pool.remove(g)
	84	plan.append({"mppt": m, "lengths": grp})
	85	plan.sort(key=lambda p: p["mppt"])
	86	return plan, lengths
	87
	88
	89	def nsrdb_extreme_min(lat, lon):
	90	"""Pull the site's NSRDB historical min air temperature (NEC 690.7 'lowest
	91	expected ambient'). Uses pvlib's PSM3 client directly (vocmax 1.0.4 is broken
	92	against pvlib 0.15 — its NSRDB pull is run separately in the pinned vocmax venv).
	93	Returns (tmin_C, source_str) or (None, reason)."""
	94	key = os.environ.get("NREL_API_KEY")
	95	email = os.environ.get("NREL_EMAIL")
	96	if not key:
	97	return None, "NREL_API_KEY not set (using documented design low)"
	98	if not email:
	99	return None, "NREL_EMAIL not set (NSRDB requires an email; using documented design low)"
	100	try:
	101	from pvlib import iotools
	102	except Exception as e: # noqa
	103	return None, f"pvlib.iotools import failed: {e}"
	104	# pvlib renamed get_psm3 -> get_nsrdb_psm3; support both.
	105	fn = getattr(iotools, "get_nsrdb_psm3", None) or getattr(iotools, "get_psm3", None)
	106	if fn is None:
	107	return None, "no NSRDB PSM3 function in this pvlib"
	108	tmins = []
	109	for yr in ("2020", "2019", "2018"): # multi-year for a robust extreme
	110	try:
	111	data, _ = fn(latitude=lat, longitude=lon, api_key=key, email=email,
	112	names=yr, map_variables=True, leap_day=True)
	113	col = "temp_air" if "temp_air" in data else (
	114	"Temperature" if "Temperature" in data else None)
	115	if col:
	116	tmins.append(float(data[col].min()))
	117	except Exception as e: # noqa
	118	if not tmins:
	119	return None, f"NSRDB fetch failed ({type(e).__name__}: {e})"
	120	break
	121	if not tmins:
	122	return None, "NSRDB returned no temperature data"
	123	return min(tmins), f"NSRDB PSM3 via pvlib ({len(tmins)} yr min)"
	124
	125
	126	def pvlib_voc_vmp(cfg, t_cold_C):
	127	"""Independent single-diode cross-check via the CEC 6-parameter model
	128	(fit_cec_sam, backed by the SAM solver in PySAM — more robust than fit_desoto).
	129	Returns dict or {'error':...}."""
	130	try:
	131	from pvlib.ivtools.sdm import fit_cec_sam
	132	from pvlib.pvsystem import calcparams_cec, singlediode
	133	except Exception as e: # noqa
	134	return {"error": f"pvlib import failed: {e}"}
	135	voc = require(cfg, "panel.voc_v"); vmp = require(cfg, "panel.vmp_v")
	136	isc = require(cfg, "panel.isc_a"); imp = require(cfg, "panel.imp_a")
	137	a_sc = require(cfg, "panel.isc_tempco_pct_per_C") / 100.0 * isc # A/C
	138	b_voc = require(cfg, "panel.voc_tempco_pct_per_C") / 100.0 * voc # V/C
	139	g_pmp = require(cfg, "panel.pmax_tempco_pct_per_C") # %/C
	140	cells = int(require(cfg, "panel.cells"))
	141	try:
	142	I_L, I_o, R_s, R_sh, a_ref, Adj = fit_cec_sam(
	143	celltype="monoSi", v_mp=vmp, i_mp=imp, v_oc=voc, i_sc=isc,
	144	alpha_sc=a_sc, beta_voc=b_voc, gamma_pmp=g_pmp, cells_in_series=cells)
	145
	146	def vov(temp_c, g=1000.0):
	147	p = calcparams_cec(g, temp_c, alpha_sc=a_sc, a_ref=a_ref, I_L_ref=I_L,
	148	I_o_ref=I_o, R_sh_ref=R_sh, R_s=R_s, Adjust=Adj)
	149	sd = singlediode(*p)
	150	return float(sd["v_oc"]), float(sd["v_mp"])
	151
	152	voc_cold, vmp_cold = vov(t_cold_C)
	153	_, vmp_hot = vov(DESIGN_HOT_CELL_C)
	154	return {"voc_cold_pvlib": voc_cold, "vmp_cold_pvlib": vmp_cold,
	155	"vmp_hot_pvlib": vmp_hot, "method": "pvlib CEC single-diode (fit_cec_sam)"}
	156	except Exception as e: # noqa
	157	return {"error": f"fit/solve failed ({type(e).__name__}: {e})"}
	158
	159
	160	def main():
	161	ap = argparse.ArgumentParser(description=__doc__)
	162	ap.add_argument("--phase2", action="store_true",
	163	help="apply the phase2: overlay (full 31-panel pallet, EG4 18kPV)")
	164	args = ap.parse_args()
	165	cfg = load_site(phase2=args.phase2)
	166	p2 = is_phase2(cfg)
	167	banner("01 PV STRING SIZING (NEC 690.7 cold-Voc + MPPT window)"
	168	+ (" [PHASE 2 — full pallet, EG4 18kPV]" if p2 else ""))
	169
	170	lat = require(cfg, "site.latitude"); lon = require(cfg, "site.longitude")
	171	voc = require(cfg, "panel.voc_v"); vmp = require(cfg, "panel.vmp_v")
	172	pmp = require(cfg, "panel.pmp_w"); imp = require(cfg, "panel.imp_a")
	173	isc = require(cfg, "panel.isc_a")
	174	b_voc = require(cfg, "panel.voc_tempco_pct_per_C")
	175	a_isc = require(cfg, "panel.isc_tempco_pct_per_C")
	176	g_pmp = require(cfg, "panel.pmax_tempco_pct_per_C")
	177	inv_abs = require(cfg, "inverter.pv_max_voc_v") # absolute do-not-exceed (500 P1 / 600 P2)
	178	inv_design = require(cfg, "inverter.pv_design_voc_ceiling_v") # design ceiling (480 P1 / 550 P2 fault)
	179	mppt_lo = require(cfg, "inverter.mppt_v_min")
	180	mppt_hi = require(cfg, "inverter.mppt_v_max")
	181	n_mppt = int(require(cfg, "inverter.mppt_count"))
	182	modules = int(require(cfg, "array.module_count"))
	183	t_low_doc = require(cfg, "site.design_low_temp_C")
	184	if not p2: # Phase-1 6000XP scalars (per-MPPT single-string); Phase-2 uses per-MPPT lists below
	185	p_mppt_max = require(cfg, "inverter.pv_max_power_w_per_mppt")
	186	p_mppt_os = require(cfg, "inverter.pv_rec_max_power_w") / 2.0
	187	i_in_max = require(cfg, "inverter.pv_max_input_a_per_mppt")
	188	isc_in_max = require(cfg, "inverter.pv_max_isc_a_per_mppt")
	189
	190	result("site", f"{lat},{lon}")
	191	result("panel Voc / Vmp / Pmp", f"{voc} / {vmp} / {pmp}", "V,V,W")
	192	result("Voc tempco (beta)", b_voc, "%/C")
	193	result("inverter Voc ceiling", f"{inv_design} design / {inv_abs} absolute", "V")
	194	result("MPPT tracking window", f"{mppt_lo}-{mppt_hi}", "V")
	195
	196	# --- Tmin: documented vs NSRDB; use the colder (conservative) ---------------
	197	t_nsrdb, src = nsrdb_extreme_min(lat, lon)
	198	if t_nsrdb is not None:
	199	t_min = min(t_low_doc, t_nsrdb)
	200	result("Tmin NSRDB", round(t_nsrdb, 1), "C", src)
	201	else:
	202	t_min = t_low_doc
	203	result("Tmin NSRDB", "unavailable", "", src)
	204	result("Tmin used (binding)", t_min, "C",
	205	"colder of documented/NSRDB; NEC 690.7 lowest expected ambient")
	206
	207	# --- (A) analytic cold-Voc per module + Vmp temp behavior -------------------
	208	voc_cold = analytic_voc(voc, b_voc, t_min)
	209	beta_vmp_pct = g_pmp - a_isc # Vmp tempco ~ Pmp tempco - Imp(~Isc) tempco
	210	vmp_cold = analytic_v(vmp, beta_vmp_pct, t_min)
	211	vmp_hot = analytic_v(vmp, beta_vmp_pct, DESIGN_HOT_CELL_C)
	212	result("Voc(module, Tmin) analytic", round(voc_cold, 2), "V", "690.7 linear (temp only)")
	213	result("derived Vmp tempco", round(beta_vmp_pct, 3), "%/C", "gamma(Pmp)-alpha(Isc)")
	214
	215	# bifacial rear-gain raises open-circuit voltage — add to the cold Voc for the
	216	# binding ceiling check (per adversarial review; worst-case cold + bifacial).
	217	cells_s = int(get(cfg, "panel.cells_electrical_series", 72))
	218	rear_frac = float(get(cfg, "panel.bifacial_rear_fraction", 0.0))
	219	bif = float(get(cfg, "panel.bifaciality", 0.0))
	220	delta_bif = bifacial_voc_adder(cells_s, rear_frac, bif) if rear_frac else 0.0
	221	voc_cold_design = voc_cold + delta_bif
	222	result("bifacial Voc adder", f"+{delta_bif:.2f}", "V/module",
	223	f"rear {rear_frac} x bifaciality {bif}; Ns={cells_s}")
	224	result("Voc(module) cold+bifacial", round(voc_cold_design, 2), "V",
	225	"BINDING value for ceiling check")
	226
	227	# --- (C) pvlib cross-check --------------------------------------------------
	228	pv = pvlib_voc_vmp(cfg, t_min)
	229	if "error" in pv:
	230	result("pvlib cross-check", "FAILED", "", pv["error"])
	231	else:
	232	result("Voc(module, Tmin) pvlib", round(pv["voc_cold_pvlib"], 2), "V", pv["method"])
	233	diff = pv["voc_cold_pvlib"] - voc_cold
	234	result(" analytic vs pvlib dVoc", f"{diff:+.2f}", "V",
	235	"agreement check (should be < ~2 V)")
	236
	237	# --- string length sweep ----------------------------------------------------
	238	print("\n Cold-Voc string check (binding safety constraint):")
	239	print(f" {'N':>3} {'Voc_cold[V]':>12} {f'<={inv_design:.0f}?':>8} {f'<={inv_abs:.0f}?':>8} "
	240	f"{f'margin{inv_design:.0f}':>11}")
	241	max_ok = 0
	242	rows = []
	243	for n in range(4, 11):
	244	sv = n * voc_cold_design
	245	ok_design = sv <= inv_design
	246	ok_abs = sv <= inv_abs
	247	if ok_design:
	248	max_ok = n
	249	rows.append({"N": n, "voc_cold_string_V": round(sv, 1),
	250	"le_design": ok_design, "le_abs": ok_abs,
	251	"margin_to_design_V": round(inv_design - sv, 1)})
	252	print(f" {n:>3} {sv:>12.1f} {str(ok_design):>8} {str(ok_abs):>8} "
	253	f"{inv_design - sv:>+11.1f}")
	254	result(f"MAX modules/series (<={inv_design:.0f}V)", max_ok, "", "NEC 690.7 binding result")
	255
	256	# =====================================================================
	257	# PHASE 2 — full pallet across the EG4 18kPV's asymmetric 3-MPPT inputs
	258	# =====================================================================
	259	if p2:
	260	usable_a = require(cfg, "inverter.pv_max_usable_a_per_mppt")
	261	isc_a_list = require(cfg, "inverter.pv_max_isc_a_per_mppt")
	262	inputs_pm = require(cfg, "inverter.inputs_per_mppt")
	263	p_total = require(cfg, "inverter.pv_max_power_w")
	264	p_rec = require(cfg, "inverter.pv_rec_max_power_w")
	265	max_s = max_ok # NEC 690.7 result (<= design fault ceiling)
	266	plan, lengths = plan_phase2_strings(modules, max_s, inputs_pm)
	267
	268	print("\n Phase-2 string layout "
	269	f"({modules} panels, max {max_s}S, {sum(inputs_pm)} inputs {inputs_pm}):")
	270	result("layout", " ".join(
	271	f"MPPT{e['mppt']+1}={'+'.join(str(x) for x in e['lengths'])}S" for e in plan))
	272
	273	def mk(b):
	274	return "ok" if b else "XX"
	275
	276	per_mppt, all_ok = [], True
	277	print(f"\n {'':6}{'strings':>9}{'coldVoc':>11}{'coldVmp':>11}{'hotVmp':>10}"
	278	f"{'Isc/lim':>12}{'Imp/usable':>14}{'power':>8}")
	279	for e in plan:
	280	m, L = e["mppt"], e["lengths"]
	281	npar = len(L)
	282	equal = len(set(L)) == 1
	283	ns, ns_min = max(L), min(L)
	284	cold_voc = ns * voc_cold_design # longest string -> worst cold Voc
	285	cold_vmp = ns * vmp_cold
	286	hot_vmp = ns_min * vmp_hot # shortest string -> lowest hot Vmp
	287	imp_m, isc_m = npar * imp, npar * isc # combined into this MPPT
	288	pwr = sum(L) * pmp
	289	voc_ok = cold_voc <= inv_design
	290	vhi_ok = cold_vmp <= mppt_hi
	291	vlo_ok = hot_vmp >= mppt_lo
	292	isc_ok = isc_m <= isc_a_list[m] # SAFETY: combined Isc <= MPPT Isc rating
	293	use_ok = imp_m <= usable_a[m] # harvest: > usable just clips at MPP peak
	294	ok = equal and voc_ok and vhi_ok and vlo_ok and isc_ok
	295	all_ok = all_ok and ok
	296	imp_cell = f"{imp_m:.1f}/{usable_a[m]}" + ("" if use_ok else " clip")
	297	print(f" MPPT{m+1} {f'{npar}x{ns}S':>9}"
	298	f"{f'{cold_voc:.0f}V {mk(voc_ok)}':>11}{f'{cold_vmp:.0f}V {mk(vhi_ok)}':>11}"
	299	f"{f'{hot_vmp:.0f}V {mk(vlo_ok)}':>10}"
	300	f"{f'{isc_m:.1f}/{isc_a_list[m]} {mk(isc_ok)}':>12}"
	301	f"{imp_cell:>14}{pwr:>7}W")
	302	per_mppt.append({
	303	"mppt": m + 1, "n_parallel": npar, "n_series": ns, "lengths": L,
	304	"equal_parallel": equal, "string_cold_voc_V": round(cold_voc, 1),
	305	"string_cold_vmp_V": round(cold_vmp, 1), "string_hot_vmp_V": round(hot_vmp, 1),
	306	"combined_imp_A": round(imp_m, 2), "usable_a_limit": usable_a[m],
	307	"combined_isc_A": round(isc_m, 2), "isc_a_limit": isc_a_list[m],
	308	"current_clips_at_mpp": not use_ok, "power_W": pwr,
	309	"checks": {"voc": voc_ok, "vmp_hi": vhi_ok, "vmp_lo": vlo_ok,
	310	"isc": isc_ok, "equal_parallel": equal},
	311	})
	312
	313	worst_voc = max(p["string_cold_voc_V"] for p in per_mppt)
	314	max_series = max(max(e["lengths"]) for e in plan)
	315	min_series = min(min(e["lengths"]) for e in plan)
	316	n_strings = sum(len(e["lengths"]) for e in plan)
	317	array_dc = sum(p["power_W"] for p in per_mppt)
	318	any_clip = any(p["current_clips_at_mpp"] for p in per_mppt)
	319	pwr_ok = array_dc <= p_total
	320
	321	print()
	322	result("binding cold Voc (longest string)", round(worst_voc, 1), "V",
	323	f"{max_series}S <= {inv_design} fault ({'PASS' if worst_voc <= inv_design else 'FAIL'}); "
	324	f"margin {inv_design - worst_voc:.0f}V to fault / {inv_abs - worst_voc:.0f}V to {inv_abs} abs")
	325	result("array DC total", array_dc, "W",
	326	f"<= {p_total} max-utilized ({'PASS' if pwr_ok else 'OVER'}) / {p_rec} recommended")
	327	if any_clip:
	328	clipped = [p for p in per_mppt if p["current_clips_at_mpp"]]
	329	for p in clipped:
	330	result(f" MPPT{p['mppt']} peak-current note",
	331	f"Imp {p['combined_imp_A']}A > {p['usable_a_limit']}A usable",
	332	"", f"SAFE harvest cap only: Isc {p['combined_isc_A']}A < "
	333	f"{p['isc_a_limit']}A MPPT rating; inverter clips ~"
	334	f"{p['combined_imp_A']-p['usable_a_limit']:.1f}A at rare full-STC peaks")
	335	verdict = all_ok and pwr_ok
	336	result("OVERALL string verdict", "PASS" if verdict else "REVIEW",
	337	"", "per-MPPT voltage+Isc+equal-parallel all pass" if verdict else "see flags")
	338
	339	dump_result("01_string" + suffix(cfg), {
	340	"phase": "phase2", "inverter": require(cfg, "inverter.model"),
	341	"tmin_C": t_min, "tmin_source": src if t_nsrdb is None else "NSRDB",
	342	"voc_cold_module_temp_V": round(voc_cold, 2),
	343	"bifacial_adder_V": round(delta_bif, 2),
	344	"voc_cold_module_V": round(voc_cold_design, 2),
	345	"voc_cold_module_pvlib_V": pv.get("voc_cold_pvlib"),
	346	"max_modules_series_le_design": max_ok,
	347	"modules_total": modules, "n_strings": n_strings,
	348	"max_string_series": max_series, "min_string_series": min_series,
	349	"n_series": max_series, # back-compat: worst-case (longest) string
	350	"string_cold_voc_V": round(worst_voc, 1),
	351	"string_imp_A": imp, "string_isc_A": isc, # per single string (one homerun each)
	352	"pv_vref_worst_V": round(min_series * vmp, 1), # lowest-Vmp string -> worst PV Vdrop% (for 03)
	353	"array_dc_W": array_dc,
	354	"mppt_window_V": [mppt_lo, mppt_hi],
	355	"inv_design_ceiling_V": inv_design, "inv_abs_ceiling_V": inv_abs,
	356	"margin_to_design_V": round(inv_design - worst_voc, 1),
	357	"margin_to_abs_V": round(inv_abs - worst_voc, 1),
	358	"margin_to_500_V": round(inv_abs - worst_voc, 1), # legacy key name = margin to abs
	359	"layout": plan, "per_mppt": per_mppt, "any_current_clip": any_clip,
	360	"verdict": "PASS" if verdict else "REVIEW", "sweep": rows,
	361	})
	362	return
	363
	364	# --- recommended design: fill the 2 MPPTs evenly ----------------------------
	365	per_mppt = modules // n_mppt
	366	n_series = per_mppt # one string per MPPT (EG4 'no combiner needed')
	367	string_voc_cold = n_series * voc_cold_design
	368	string_vmp_cold = n_series * vmp_cold
	369	string_vmp_hot = n_series * vmp_hot
	370	string_pmp = n_series * pmp
	371
	372	print("\n Recommended configuration:")
	373	result("topology", f"{n_series}S x 1P per MPPT, {n_mppt} MPPTs = {n_series*n_mppt} modules")
	374	result("string cold Voc", round(string_voc_cold, 1), "V",
	375	f"<= {inv_design} design ({'PASS' if string_voc_cold<=inv_design else 'FAIL'})")
	376	result("string cold Voc vs 500 abs", f"{string_voc_cold:.1f}/{inv_abs}",
	377	"V", f"{(inv_abs-string_voc_cold):.0f} V margin")
	378	result("string cold Vmp (analytic)", round(string_vmp_cold, 1), "V",
	379	f"<= {mppt_hi} MPPT max ({'PASS' if string_vmp_cold<=mppt_hi else 'FAIL'})")
	380	if "error" not in pv:
	381	result("string cold Vmp (pvlib)", round(n_series*pv['vmp_cold_pvlib'], 1), "V",
	382	f"<= {mppt_hi} ({'PASS' if n_series*pv['vmp_cold_pvlib']<=mppt_hi else 'CHECK'})")
	383	result("string hot Vmp (pvlib)", round(n_series*pv['vmp_hot_pvlib'], 1), "V",
	384	f">= {mppt_lo} MPPT min ({'PASS' if n_series*pv['vmp_hot_pvlib']>=mppt_lo else 'FAIL'})")
	385	result("string hot Vmp (analytic)", round(string_vmp_hot, 1), "V",
	386	f">= {mppt_lo} ({'PASS' if string_vmp_hot>=mppt_lo else 'FAIL'})")
	387
	388	# --- per-MPPT power / current -----------------------------------------------
	389	print("\n Per-MPPT loading:")
	390	result("string power (DC)", round(string_pmp), "W",
	391	f"vs {p_mppt_max} usable / {p_mppt_os:.0f} oversize cap")
	392	result("string Imp", imp, "A", f"vs {i_in_max} max input ({'PASS' if imp<=i_in_max else 'FAIL'})")
	393	result("string Isc", isc, "A", f"vs {isc_in_max} Isc rating ({'PASS' if isc<=isc_in_max else 'FAIL'})")
	394	result("array DC total", round(string_pmp*n_mppt), "W")
	395
	396	verdict = (string_voc_cold <= inv_design and string_vmp_hot >= mppt_lo
	397	and imp <= i_in_max and isc <= isc_in_max)
	398	result("OVERALL string verdict", "PASS" if verdict else "REVIEW")
	399
	400	dump_result("01_string", {
	401	"tmin_C": t_min, "tmin_source": src if t_nsrdb is None else "NSRDB",
	402	"voc_cold_module_temp_V": round(voc_cold, 2),
	403	"bifacial_adder_V": round(delta_bif, 2),
	404	"voc_cold_module_V": round(voc_cold_design, 2),
	405	"voc_cold_module_pvlib_V": pv.get("voc_cold_pvlib"),
	406	"max_modules_series_le_480": max_ok,
	407	"n_series": n_series, "n_strings": n_mppt, "modules_total": n_series*n_mppt,
	408	"string_cold_voc_V": round(string_voc_cold, 1),
	409	"inv_design_ceiling_V": inv_design, "inv_abs_ceiling_V": inv_abs,
	410	"margin_to_480_V": round(inv_design - string_voc_cold, 1),
	411	"margin_to_500_V": round(inv_abs - string_voc_cold, 1),
	412	"string_cold_vmp_V": round(string_vmp_cold, 1),
	413	"string_hot_vmp_V": round(string_vmp_hot, 1),
	414	"mppt_window_V": [mppt_lo, mppt_hi],
	415	"string_power_W": round(string_pmp), "string_imp_A": imp, "string_isc_A": isc,
	416	"array_dc_W": round(string_pmp*n_mppt),
	417	"verdict": "PASS" if verdict else "REVIEW",
	418	"sweep": rows,
	419	})
	420
	421
	422	if __name__ == "__main__":
	423	main()

scripts/01b_vocmax.py +83 -0

…	…	@@ -0,0 +1,83 @@
	1	"""01b — vocmax named-tool corroboration of the cold-Voc result.
	2
	3	CLAUDE.md names `vocmax` as the NEC 690.7 grounding tool. vocmax 1.0.4 is incompatible
	4	with the main env's pvlib 0.15 (it imports the removed get_psm3), so it runs in a pinned
	5	venv: ~/.venvs/prsm-vocmax (python3.9 + pvlib 0.9.5 + numpy<2).
	6
	7	This computes module Voc at the design low temperature with vocmax's own Sandia Voc
	8	model (vocmax.calculate_voc) and derives the max string length vs the inverter ceilings —
	9	a fourth, independent check on the 7S result from 01_string_sizing.py.
	10
	11	NOTE: vocmax's full value is its NSRDB statistical worst-case (P99.5 etc.), which needs
	12	an NREL key. At full-sun (Ee=1) the Sandia Voc reduces to the linear 690.7 form, so this
	13	offline run confirms the per-module Voc; the NSRDB workflow is the open item.
	14
	15	Run: ~/.venvs/prsm-vocmax/bin/python scripts/01b_vocmax.py
	16	"""
	17	import argparse
	18	import vocmax
	19	from common import load_site, require, banner, result, dump_result, is_phase2, suffix
	20
	21
	22	def main():
	23	ap = argparse.ArgumentParser()
	24	ap.add_argument("--phase2", action="store_true",
	25	help="apply the phase2: overlay (EG4 18kPV ceilings, full pallet)")
	26	args = ap.parse_args()
	27	cfg = load_site(phase2=args.phase2)
	28	p2 = is_phase2(cfg)
	29	banner("01b VOCMAX named-tool corroboration (offline, design-low temp)"
	30	+ (" [PHASE 2 — EG4 18kPV]" if p2 else ""))
	31	voc = require(cfg, "panel.voc_v")
	32	b_voc_pct = require(cfg, "panel.voc_tempco_pct_per_C")
	33	cells = int(require(cfg, "panel.cells_electrical_series"))
	34	t_min = require(cfg, "site.design_low_temp_C")
	35	inv_design = require(cfg, "inverter.pv_design_voc_ceiling_v")
	36	inv_abs = require(cfg, "inverter.pv_max_voc_v")
	37
	38	module = {
	39	"Voco": voc,
	40	"Bvoco": b_voc_pct / 100.0 * voc, # V/C
	41	"cells_in_series": cells,
	42	"n_diode": 1.1,
	43	"FD": 1.0,
	44	}
	45	result("vocmax version", vocmax.__version__)
	46	result("module Voco / Bvoco", f"{module['Voco']} / {module['Bvoco']:.4f}", "V , V/C")
	47
	48	voc_stc = float(vocmax.calculate_voc(1000.0, 25.0, module))
	49	voc_cold = float(vocmax.calculate_voc(1000.0, t_min, module)) # full-sun, design low
	50	result("vocmax Voc @ 25C", round(voc_stc, 2), "V", "should reproduce Voco")
	51	result("vocmax Voc @ Tmin", round(voc_cold, 2), "V", f"{t_min} C, Ee=1")
	52
	53	max_series_design = int(inv_design // voc_cold)
	54	max_series_abs = int(inv_abs // voc_cold)
	55	# String to validate: phase2 = the design's longest string (binding max = max_series_design);
	56	# phase1 = the even-fill per-MPPT length (module_count // mppt_count).
	57	n_series = max_series_design if p2 else (
	58	require(cfg, "array.module_count") // require(cfg, "inverter.mppt_count"))
	59	string_cold = n_series * voc_cold
	60	result(f"{n_series}S string cold Voc", round(string_cold, 1), "V",
	61	f"<= {inv_design} ({'PASS' if string_cold <= inv_design else 'FAIL'})")
	62	result(f"max modules/series <={inv_design:.0f}", max_series_design)
	63	result(f"max modules/series <={inv_abs:.0f}", max_series_abs)
	64	result("VOCMAX VERDICT", f"{n_series}S PASS" if (n_series <= max_series_design) else "REVIEW")
	65
	66	dump_result("01b_vocmax" + suffix(cfg), {
	67	"phase": "phase2" if p2 else "phase1",
	68	"vocmax_version": vocmax.__version__,
	69	"voc_module_stc_V": round(voc_stc, 2),
	70	"voc_module_cold_V": round(voc_cold, 2),
	71	"tmin_C": t_min,
	72	"design_ceiling_V": inv_design, "abs_ceiling_V": inv_abs,
	73	"string_series_checked": n_series,
	74	"string_cold_voc_V": round(string_cold, 1),
	75	"max_series_le_design": max_series_design,
	76	"max_series_le_abs": max_series_abs,
	77	"verdict": f"{n_series}S PASS" if (n_series <= max_series_design) else "REVIEW",
	78	"note": "offline full-sun Sandia Voc (=linear 690.7); NSRDB statistical run needs NREL key",
	79	})
	80
	81
	82	if __name__ == "__main__":
	83	main()

scripts/02_production.py +107 -0

…	…	@@ -0,0 +1,107 @@
	1	"""02 — Production / per-MPPT energy sanity (PVWatts v8, fixed open-rack).
	2
	3	Annual + monthly AC kWh for the ~8 kW array, with the winter (Dec/Jan) worst-case
	4	that actually governs an off-grid system. Per-MPPT DC power check vs the inverter.
	5
	6	Ground truth: NREL PVWatts V8 REST API. The host is VERIFIED empirically here
	7	(the project docs claim a 2026-05-29 migration to developer.nlr.gov; we test the
	8	canonical developer.nrel.gov first and only fall back if it fails).
	9
	10	Run: ~/.venvs/prsm-electrical/bin/python scripts/02_production.py
	11	Uses NREL_API_KEY if set, else DEMO_KEY (rate-limited but works for PVWatts).
	12	"""
	13	import os
	14	import requests
	15	from common import load_site, require, banner, result, dump_result, load_result
	16
	17	HOSTS = ["https://developer.nrel.gov", "https://developer.nlr.gov"]
	18	PATH = "/api/pvwatts/v8.json"
	19	MONTHS = ["Jan", "Feb", "Mar", "Apr", "May", "Jun",
	20	"Jul", "Aug", "Sep", "Oct", "Nov", "Dec"]
	21	DAYS = [31, 28, 31, 30, 31, 30, 31, 31, 30, 31, 30, 31]
	22
	23
	24	def call_pvwatts(params):
	25	"""Try each host; return (json, host, err)."""
	26	last = None
	27	for host in HOSTS:
	28	try:
	29	r = requests.get(host + PATH, params=params, timeout=30)
	30	if r.status_code == 200 and "outputs" in r.json():
	31	return r.json(), host, None
	32	last = f"{host}: HTTP {r.status_code} {r.text[:120]}"
	33	except Exception as e: # noqa
	34	last = f"{host}: {type(e).__name__}: {e}"
	35	return None, None, last
	36
	37
	38	def main():
	39	cfg = load_site()
	40	banner("02 PRODUCTION (PVWatts v8, fixed open-rack array_type=0)")
	41	s01 = load_result("01_string")
	42
	43	modules = int(require(cfg, "array.module_count"))
	44	pmp = require(cfg, "panel.pmp_w")
	45	kw = round(modules * pmp / 1000.0, 2)
	46	tilt = require(cfg, "array.tilt_deg")
	47	az = require(cfg, "array.azimuth_deg")
	48	lat = require(cfg, "site.latitude")
	49	lon = require(cfg, "site.longitude")
	50	key = os.environ.get("NREL_API_KEY", "DEMO_KEY")
	51
	52	result("system_capacity", kw, "kW DC", f"{modules} x {pmp}W")
	53	result("tilt / azimuth", f"{tilt} / {az}", "deg")
	54	result("api key", "NREL_API_KEY" if key != "DEMO_KEY" else "DEMO_KEY (rate-limited)")
	55
	56	params = {"api_key": key, "system_capacity": kw, "module_type": 0,
	57	"array_type": 0, "tilt": tilt, "azimuth": az, "losses": 14,
	58	"lat": lat, "lon": lon, "dc_ac_ratio": round(kw / 6.0, 2)}
	59	data, host, err = call_pvwatts(params)
	60	if data is None:
	61	result("PVWatts", "UNAVAILABLE", "", err)
	62	result("note", "production is a sanity check; safety calcs (01/03/04) do not depend on it")
	63	dump_result("02_production", {"status": "unavailable", "error": err,
	64	"system_kw": kw})
	65	raise SystemExit("PVWatts call failed; rerun with a valid NREL_API_KEY.")
	66
	67	out = data["outputs"]
	68	result("VERIFIED host", host, "", "developer.nrel.gov canonical"
	69	if "nrel" in host else "fell back to alt host")
	70	ac_annual = out["ac_annual"]
	71	ac_monthly = out["ac_monthly"]
	72	cf = out.get("capacity_factor")
	73	result("AC annual", round(ac_annual), "kWh/yr")
	74	result("capacity factor", round(cf, 1) if cf else "n/a", "%")
	75	print("\n Monthly AC (kWh) + kWh/day:")
	76	for i, m in enumerate(MONTHS):
	77	print(f" {m} {ac_monthly[i]:8.0f} {ac_monthly[i]/DAYS[i]:5.1f}/day")
	78	dec_day = ac_monthly[11] / DAYS[11]
	79	jan_day = ac_monthly[0] / DAYS[0]
	80	jun_day = ac_monthly[5] / DAYS[5]
	81	print()
	82	result("WINTER Dec / Jan kWh/day", f"{dec_day:.1f} / {jan_day:.1f}", "",
	83	"off-grid binding case")
	84	result("Summer Jun kWh/day", f"{jun_day:.1f}", "", "for contrast")
	85	result("winter:summer ratio", f"{dec_day/jun_day:.2f}", "",
	86	"NEK winter PV starvation -> generator + Phase-2 PV (Swarm §2,§6)")
	87
	88	# per-MPPT DC power check (from 01)
	89	print("\n Per-MPPT loading (DC nameplate, from 01):")
	90	result("string DC power", s01["string_power_W"], "W",
	91	f"vs 4000 usable / 5000 oversize cap per MPPT")
	92	result("array DC total", s01["array_dc_W"], "W", "vs 8000 usable / 10000 oversize")
	93	result("DC:AC ratio", round(kw / 6.0, 2), "", "winter-favorable oversizing")
	94
	95	dump_result("02_production", {
	96	"status": "ok", "verified_host": host, "system_kw": kw,
	97	"ac_annual_kwh": round(ac_annual), "capacity_factor_pct": cf,
	98	"ac_monthly_kwh": [round(x) for x in ac_monthly],
	99	"dec_kwh_day": round(dec_day, 1), "jan_kwh_day": round(jan_day, 1),
	100	"jun_kwh_day": round(jun_day, 1),
	101	"string_dc_W": s01["string_power_W"], "array_dc_W": s01["array_dc_W"],
	102	"dc_ac_ratio": round(kw / 6.0, 2),
	103	})
	104
	105
	106	if __name__ == "__main__":
	107	main()

scripts/03_conductors.py +295 -0

…	…	@@ -0,0 +1,295 @@
	1	"""03 — Conductor ampacity + voltage drop (NEC 690.8 / 310.15 / 240.4 / Ch.9 T8).
	2
	3	For each run: corrected continuous current -> required ampacity after 310.15 derates
	4	-> smallest compliant copper gauge (honoring 240.4(D)) -> upsize if voltage drop
	5	exceeds target -> OCPD (240.6) -> EGC (250.122). All NEC tables in nec_tables.py.
	6
	7	Run: ~/.venvs/prsm-electrical/bin/python scripts/03_conductors.py
	8	"""
	9	import argparse
	10	from common import (load_site, require, get, banner, result, dump_result, load_result,
	11	is_phase2, suffix)
	12	from nec_tables import (T310_16, T8_DCRES, fill_factor, temp_factor, AWG_ORDER,
	13	std_ocpd_at_least, egc_awg, max_ocpd_240_4d)
	14
	15
	16	def vdrop_pct(awg, length_ft, amps, vref, n_conductors=2):
	17	"""Voltage drop %, NEC Ch.9 Table 8 DC resistance (75C). n_conductors=2 for a
	18	2-wire DC or 1-phase circuit (out and back)."""
	19	r = T8_DCRES[awg] / 1000.0 # ohm/ft
	20	drop = n_conductors * length_ft * amps * r
	21	return 100.0 * drop / vref, drop
	22
	23
	24	def pick_gauge(required_term_a, required_derated_a, ambient_c, ccc, term_col="75",
	25	start="14"):
	26	"""Smallest copper AWG whose 75C(term) ampacity >= required_term_a AND whose
	27	90C ampacity x temp x fill >= required_derated_a."""
	28	tf = temp_factor(ambient_c, "90")
	29	ff = fill_factor(ccc)
	30	for awg in AWG_ORDER[AWG_ORDER.index(start):]:
	31	amp_term = T310_16[awg][{"60": 0, "75": 1, "90": 2}[term_col]]
	32	amp_derated = T310_16[awg][2] * tf * ff
	33	if amp_term >= required_term_a - 1e-9 and amp_derated >= required_derated_a - 1e-9:
	34	return awg, amp_term, amp_derated, tf, ff
	35	raise SystemExit("no gauge in table satisfies ampacity; extend table")
	36
	37
	38	def size_run(name, *, mode, current, vref, length_ft, target_pct, ambient_c, ccc,
	39	isc=None, term_col="75", set_ocpd=True):
	40	"""mode 'pv' -> 690.8(A)(1)+(B); mode 'continuous' -> 125% continuous (210/215/480)."""
	41	if mode == "pv":
	42	max_current = isc * 1.25 # 690.8(A)(1)
	43	req_term = max_current * 1.25 # 690.8(B)(1): 125% at terminal rating
	44	req_derated = max_current # 690.8(B)(2): after conditions of use
	45	load_for_vd = current # Imp for voltage drop
	46	ocpd_basis = max_current
	47	else: # continuous
	48	req_term = current * 1.25 # 215.2/210.19: 125% continuous
	49	req_derated = current * 1.25
	50	load_for_vd = current
	51	ocpd_basis = current * 1.25
	52
	53	awg, amp_term, amp_derated, tf, ff = pick_gauge(req_term, req_derated, ambient_c, ccc, term_col)
	54
	55	# upsize for voltage drop
	56	vd_awg = awg
	57	vd_pct, vd_v = vdrop_pct(vd_awg, length_ft, load_for_vd, vref)
	58	while vd_pct > target_pct and AWG_ORDER.index(vd_awg) < len(AWG_ORDER) - 1:
	59	vd_awg = AWG_ORDER[AWG_ORDER.index(vd_awg) + 1]
	60	vd_pct, vd_v = vdrop_pct(vd_awg, length_ft, load_for_vd, vref)
	61	final = vd_awg
	62
	63	ocpd = std_ocpd_at_least(ocpd_basis) if set_ocpd else None
	64	# 240.4(D): OCPD must not exceed the conductor's small-conductor ceiling.
	65	# Upsize the conductor until it can be protected by the required OCPD.
	66	if ocpd is not None:
	67	while (max_ocpd_240_4d(final, T310_16[final][1]) < ocpd
	68	and AWG_ORDER.index(final) < len(AWG_ORDER) - 1):
	69	final = AWG_ORDER[AWG_ORDER.index(final) + 1]
	70	ceil = max_ocpd_240_4d(final, T310_16[final][1])
	71	ocpd_note = "OK" if ocpd <= ceil else f"OCPD {ocpd}>ceil {ceil}"
	72	else:
	73	ocpd_note = "n/a"
	74
	75	# recompute voltage drop for the final (possibly upsized) gauge
	76	vd_pct, vd_v = vdrop_pct(final, length_ft, load_for_vd, vref)
	77	driver = ("ampacity" if final == awg
	78	else "voltage-drop" if final == vd_awg else "240.4(D) OCPD")
	79	egc = egc_awg(ocpd) if ocpd else None
	80
	81	res = {
	82	"run": name, "mode": mode, "length_ft": length_ft, "vref_V": vref,
	83	"current_A": round(current, 2),
	84	"req_ampacity_term_A": round(req_term, 1),
	85	"req_ampacity_derated_A": round(req_derated, 1),
	86	"ambient_C": ambient_c, "ccc": ccc, "temp_factor90": tf, "fill_factor": ff,
	87	"ampacity_gauge": awg, "ampacity_75C_A": amp_term,
	88	"ampacity_derated90_A": round(amp_derated, 1),
	89	"final_gauge_AWG": final, "gauge_driver": driver,
	90	"vdrop_pct": round(vd_pct, 3), "vdrop_V": round(vd_v, 3),
	91	"target_pct": target_pct,
	92	"ocpd_A": ocpd, "ocpd_note": ocpd_note, "egc_AWG": egc,
	93	}
	94	return res
	95
	96
	97	def report(r):
	98	result(r["run"], f"{r['current_A']} A cont", "",
	99	f"{r['mode']} basis")
	100	result(" req ampacity (term/derated)",
	101	f"{r['req_ampacity_term_A']} / {r['req_ampacity_derated_A']}", "A",
	102	f"310.15(B) Tf={r['temp_factor90']} x 310.15(C) Ff={r['fill_factor']} @ {r['ambient_C']}C, {r['ccc']}CCC")
	103	result(" ampacity-min gauge", f"{r['ampacity_gauge']} ({r['ampacity_75C_A']}A@75C)")
	104	result(" FINAL gauge", f"{r['final_gauge_AWG']} Cu", "", f"driver: {r['gauge_driver']}")
	105	result(" voltage drop", f"{r['vdrop_pct']}% ({r['vdrop_V']} V)", "",
	106	f"target <= {r['target_pct']}% ({'PASS' if r['vdrop_pct']<=r['target_pct'] else 'FAIL'}) [Ch.9 T8]")
	107	if r["ocpd_A"]:
	108	result(" OCPD / EGC", f"{r['ocpd_A']} A / {r['egc_AWG']} AWG Cu",
	109	"", f"240.6 / 250.122 ({r['ocpd_note']})")
	110
	111
	112	def phase2_conductors(cfg):
	113	"""Final-state conductors: EG4 18kPV (12 kW AC), full 31-panel pallet (4 strings),
	114	2x Docan S3 bank on a DC busbar. PV homeruns, AC feeder, per-pack + bank battery cables."""
	115	banner("03 CONDUCTORS [PHASE 2 — EG4 18kPV 12kW AC, full pallet, 2-pack bank]")
	116	s01 = load_result("01_string_phase2")
	117
	118	isc = require(cfg, "panel.isc_a"); imp = require(cfg, "panel.imp_a")
	119	pv_vref = s01["pv_vref_worst_V"] # lowest-Vmp string (7S) -> worst Vdrop%
	120	n_strings = s01["n_strings"] # 4 homeruns total
	121	ccc_pv = 2 * n_strings # both polarities of every string in the trench
	122	ac_w = require(cfg, "inverter.ac_continuous_w") # 12000
	123	ac_i = require(cfg, "inverter.ac_cont_a") # 50 (datasheet max output current)
	124	ac_v = 240.0
	125	eff = require(cfg, "inverter.discharge_eff") # 0.94
	126	vnom = require(cfg, "battery.nominal_v") # 51.2
	127	inv_dis = require(cfg, "inverter.batt_max_discharge_a") # 250
	128	npack = int(require(cfg, "battery.pack_count")) # 2
	129	runs = cfg["runs_ft"]; tgt = cfg["targets"]
	130
	131	i_bank_demand = ac_w / eff / vnom # 12 kW draw from the bank
	132	i_bank = min(i_bank_demand, inv_dis) # capped at the inverter's 250 A limit
	133	i_pack = i_bank / npack # per pack
	134
	135	result("AC output @12kW", round(ac_i, 1), "A", "datasheet max output 50 A @240V")
	136	result("bank discharge @12kW", f"{i_bank:.0f}", "A",
	137	f"{i_bank_demand:.0f}A demand capped at inverter {inv_dis}A; /{npack} packs = {i_pack:.0f}A/pack")
	138	result("PV homeruns", f"{n_strings} strings -> {ccc_pv} CCC", "", "one homerun per string, no combiner")
	139	print()
	140
	141	results = {}
	142
	143	# 1) PV string homerun — worst-case (shortest=lowest-Vmp) string; 4 strings share the trench
	144	r_pv = size_run("PV string (array->18kPV input, per string)", mode="pv",
	145	current=imp, vref=pv_vref, length_ft=runs["combiner_to_inverter"],
	146	target_pct=tgt["vdrop_dc_pct_max"], ambient_c=40, ccc=ccc_pv,
	147	isc=isc, set_ocpd=False)
	148	report(r_pv)
	149	sweep = {}
	150	for L in cfg.get("dc_run_sweep_ft", [runs["combiner_to_inverter"]]):
	151	p, _ = vdrop_pct(r_pv["final_gauge_AWG"], L, imp, pv_vref)
	152	sweep[L] = round(p, 3)
	153	result(" DC Vdrop sweep 150/200/250 ft",
	154	" / ".join(f"{L}ft:{p}%" for L, p in sweep.items()), "",
	155	f"{r_pv['final_gauge_AWG']} Cu, {ccc_pv} CCC in trench (0.70 fill)")
	156	# 690.9(A) source fusing check: MPPT1 parallels 2 strings -> backfeed from the ONE other
	157	# string = 1.25*Isc; if <= module series fuse, no source OCPD required.
	158	backfeed = round(1.25 * isc, 1); mod_fuse = require(cfg, "panel.series_fuse_a")
	159	result(" 690.9(A) source fusing", "NOT required", "",
	160	f"max parallel backfeed 1.25xIsc={backfeed}A <= module {mod_fuse}A series fuse "
	161	f"(MPPT1=2 strings; 3+ would need fuses)")
	162	r_pv["vdrop_sweep_pct"] = sweep; r_pv["n_strings"] = n_strings
	163	r_pv["source_fuse_required"] = False; r_pv["parallel_backfeed_A"] = backfeed
	164	results["pv_string"] = r_pv
	165	print()
	166
	167	# 2) AC output 12 kW / 50 A -> subfed main panel
	168	r_ac = size_run("AC output (18kPV->main panel)", mode="continuous",
	169	current=ac_i, vref=ac_v, length_ft=runs["inverter_to_loads"],
	170	target_pct=tgt["vdrop_ac_pct_max"], ambient_c=30, ccc=2)
	171	report(r_ac)
	172	results["ac_output"] = r_ac
	173	print()
	174
	175	# 3) Battery per-pack (pack -> busbar), one per pack
	176	r_pack = size_run("Battery per-pack (pack->busbar)", mode="continuous",
	177	current=i_pack, vref=vnom, length_ft=runs["pack_to_busbar"],
	178	target_pct=tgt["vdrop_battery_pct_max"], ambient_c=30, ccc=2)
	179	report(r_pack)
	180	r_pack["count"] = npack
	181	results["battery_per_pack"] = r_pack
	182	print()
	183
	184	# 4) Battery bank (busbar -> 18kPV) at the 250 A bank current. OCP is per-pack (Class-T,
	185	# finalized in 04); here size the conductor for ampacity + present the practical parallel set.
	186	r_bank = size_run("Battery bank (busbar->18kPV)", mode="continuous",
	187	current=i_bank, vref=vnom, length_ft=runs["inverter_to_battery"],
	188	target_pct=tgt["vdrop_battery_pct_max"], ambient_c=30, ccc=2,
	189	set_ocpd=False)
	190	report(r_bank)
	191	# practical alternative: parallel sets per polarity (flexible vs one stiff 400-kcmil cable)
	192	half = i_bank / 2.0
	193	vp_2_0, _ = vdrop_pct("2/0", runs["inverter_to_battery"], half, vnom)
	194	vp_4_0, _ = vdrop_pct("4/0", runs["inverter_to_battery"], half, vnom)
	195	amp_2_0 = 2 * T310_16["2/0"][1]; amp_4_0 = 2 * T310_16["4/0"][1]
	196	req_cont = round(i_bank * 1.25, 1)
	197	result(" parallel-set alt (2 per polarity)",
	198	f"2x2/0={amp_2_0}A (Vd {round(vp_2_0,3)}%) | 2x4/0={amp_4_0}A (Vd {round(vp_4_0,3)}%)", "",
	199	f">= {req_cont}A (125%x{i_bank:.0f}); coordinates w/ 2x175A pack fuses (350A aggregate)")
	200	r_bank["req_continuous_A"] = req_cont
	201	r_bank["parallel_alt"] = {"2x2/0_A": amp_2_0, "2x4/0_A": amp_4_0,
	202	"single_min": r_bank["final_gauge_AWG"]}
	203	results["battery_bank"] = r_bank
	204	print()
	205
	206	result("bank disconnect", "250 A+ DC, lockable", "", "690.15/706.30/480.7 service isolation")
	207	dump_result("03_conductors" + suffix(cfg), results)
	208
	209
	210	def main():
	211	ap = argparse.ArgumentParser()
	212	ap.add_argument("--phase2", action="store_true",
	213	help="final state: EG4 18kPV 12kW, full pallet, 2-pack bank")
	214	args = ap.parse_args()
	215	cfg = load_site(phase2=args.phase2)
	216	if is_phase2(cfg):
	217	phase2_conductors(cfg)
	218	return
	219	banner("03 CONDUCTORS (NEC 690.8 ampacity + 310.15 derates + voltage drop)")
	220	s01 = load_result("01_string")
	221
	222	isc = require(cfg, "panel.isc_a")
	223	imp = require(cfg, "panel.imp_a")
	224	n_series = s01["n_series"]
	225	vmp_string = round(n_series * require(cfg, "panel.vmp_v"), 1)
	226	ac_w = require(cfg, "inverter.ac_continuous_w")
	227	ac_v = 240.0
	228	vnom_batt = require(cfg, "battery.nominal_v")
	229	eff = require(cfg, "inverter.discharge_eff")
	230	runs = cfg["runs_ft"]
	231	tgt = cfg["targets"]
	232
	233	i_batt = ac_w / eff / vnom_batt
	234	i_ac = ac_w / ac_v
	235	result("PV Imp / Isc", f"{imp} / {isc}", "A")
	236	result("string Vmp (DC)", vmp_string, "V", f"{n_series}S")
	237	result("battery current @ 6kW", round(i_batt, 1), "A", "ac_w/eff/Vnom")
	238	result("AC output current", round(i_ac, 1), "A", "6kW/240V split-phase")
	239	print()
	240
	241	results = {}
	242
	243	# 1) PV string source/output, array -> inverter (one per MPPT). 2 strings in one
	244	# trench conduit -> 4 CCC. Conservative ambient 40C for above-grade segments.
	245	dc_len = runs["combiner_to_inverter"]
	246	r_pv = size_run("PV string (array->inverter, per MPPT)", mode="pv",
	247	current=imp, vref=vmp_string, length_ft=dc_len,
	248	target_pct=tgt["vdrop_dc_pct_max"], ambient_c=40, ccc=4,
	249	isc=isc, set_ocpd=False)
	250	report(r_pv)
	251	# DC voltage-drop sweep across owner's stated 150-250 ft range, chosen gauge
	252	sweep = {}
	253	for L in cfg.get("dc_run_sweep_ft", [dc_len]):
	254	p, v = vdrop_pct(r_pv["final_gauge_AWG"], L, imp, vmp_string)
	255	sweep[L] = round(p, 3)
	256	result(" DC Vdrop sweep 150/200/250 ft",
	257	" / ".join(f"{L}ft:{p}%" for L, p in sweep.items()), "",
	258	f"gauge {r_pv['final_gauge_AWG']} holds <= {tgt['vdrop_dc_pct_max']}%")
	259	r_pv["vdrop_sweep_pct"] = sweep
	260	results["pv_string"] = r_pv
	261	print()
	262
	263	# 2) Battery -> inverter (high current, short). Indoor 30C, 2 CCC.
	264	r_batt = size_run("Battery <-> inverter", mode="continuous",
	265	current=i_batt, vref=vnom_batt, length_ft=runs["inverter_to_battery"],
	266	target_pct=tgt["vdrop_battery_pct_max"], ambient_c=30, ccc=2)
	267	report(r_batt)
	268	# recommended upsize for low loss / margin
	269	up = AWG_ORDER[AWG_ORDER.index(r_batt["final_gauge_AWG"]) + 2]
	270	up_pct, _ = vdrop_pct(up, runs["inverter_to_battery"], i_batt, vnom_batt)
	271	result(" recommended upsize", f"{up} Cu", "", f"Vdrop {round(up_pct,3)}% (margin + low loss)")
	272	r_batt["recommended_upsize_AWG"] = up
	273	results["battery"] = r_batt
	274	print()
	275
	276	# 3) AC output -> subfed main panel. Indoor 30C, 2 CCC (L1/L2).
	277	r_ac = size_run("AC output (inverter->main panel)", mode="continuous",
	278	current=i_ac, vref=ac_v, length_ft=runs["inverter_to_loads"],
	279	target_pct=tgt["vdrop_ac_pct_max"], ambient_c=30, ccc=2)
	280	report(r_ac)
	281	results["ac_output"] = r_ac
	282	print()
	283
	284	# 4) Battery Class-T fuse coordination (size in 04; here confirm cable >= fuse)
	285	batt_ocpd = r_batt["ocpd_A"]
	286	cable_amp = T310_16[r_batt["final_gauge_AWG"]][1]
	287	result("Battery Class-T fuse (prelim)", f"{batt_ocpd} A",
	288	"", f"<= cable {r_batt['final_gauge_AWG']} ampacity {cable_amp}A "
	289	f"({'OK' if batt_ocpd<=cable_amp else 'UPSIZE CABLE'}); final in 04_battery")
	290
	291	dump_result("03_conductors", results)
	292
	293
	294	if __name__ == "__main__":
	295	main()

scripts/04_battery.py +235 -0

…	…	@@ -0,0 +1,235 @@
	1	"""04 — Battery discharge / C-rate / runtime + Class-T fuse (NEC 240.6 / 690.71 / 480).
	2
	3	Confirms that at full AC output the battery current is within EVERY limit (inverter,
	4	JK-BMS trip, EVE cell-honest), checks the surge transient, computes C-rate + runtime,
	5	and finalizes the Class-T fuse coordinated with the cable from 03.
	6
	7	Run: ~/.venvs/prsm-electrical/bin/python scripts/04_battery.py
	8	"""
	9	import argparse
	10	from common import (load_site, require, get, banner, result, dump_result, load_result,
	11	is_phase2, suffix)
	12	from nec_tables import std_ocpd_at_least, T310_16
	13
	14
	15	def phase2_battery(cfg):
	16	"""Final-state 2x Docan S3 bank on the EG4 18kPV (12 kW / 250 A bank discharge).
	17	The bank current splits across packs; per-pack must clear the JK-BMS/EVE limits, and
	18	the inverter's 250 A cap is the binding bank limit. Per-pack Class-T is primary OCP."""
	19	banner("04 BATTERY [PHASE 2 — 2x Docan S3 bank, EG4 18kPV 12kW]")
	20	cond = load_result("03_conductors_phase2")
	21	pack_cable = cond["battery_per_pack"]
	22	bank_cable = cond["battery_bank"]
	23
	24	vnom = require(cfg, "battery.nominal_v")
	25	cap_ah = require(cfg, "battery.capacity_ah")
	26	usable_kwh = require(cfg, "battery.usable_kwh")
	27	dod = require(cfg, "battery.dod_design")
	28	npack = int(require(cfg, "battery.pack_count"))
	29	ac_w = require(cfg, "inverter.ac_continuous_w")
	30	surge_nopv = require(cfg, "inverter.ac_surge_w_no_pv_10min")
	31	surge_pv = require(cfg, "inverter.ac_surge_w_with_pv_5min")
	32	eff = require(cfg, "inverter.discharge_eff")
	33	inv_dis = require(cfg, "inverter.batt_max_discharge_a")
	34	inv_chg = require(cfg, "inverter.batt_max_charge_a")
	35	bms_trip = require(cfg, "battery.bms_discharge_ocp_a")
	36	bms_delay = require(cfg, "battery.bms_ocp_delay_s")
	37	bms_sc = require(cfg, "battery.bms_short_circuit_a")
	38	bms_market = require(cfg, "battery.bms_continuous_a")
	39	cell_cont = require(cfg, "battery.cell_continuous_a")
	40
	41	i_bank_demand = ac_w / eff / vnom
	42	i_bank = min(i_bank_demand, inv_dis)
	43	i_pack = i_bank / npack
	44	result("inverter AC continuous", ac_w, "W", "EG4 18kPV @240V")
	45	result("bank discharge @12kW", round(i_bank, 1), "A",
	46	f"{i_bank_demand:.1f}A demand capped at inverter {inv_dis}A bank limit")
	47	result("per-pack discharge", round(i_pack, 1), "A", f"bank / {npack} packs")
	48
	49	print("\n Bank-level limit (the inverter cap is binding at 12 kW):")
	50	result(" vs inverter max discharge", f"{i_bank:.1f} / {inv_dis}", "A",
	51	f"{'PASS' if i_bank <= inv_dis else 'FAIL'} (headroom {inv_dis-i_bank:.1f}A)")
	52	result(" 2-pack combined BMS / cell", f"{npack*bms_trip} / {npack*cell_cont}", "A",
	53	f"both > inverter {inv_dis}A -> the bank is NOT the binding limit (inverter is)")
	54
	55	print("\n Per-pack limit stack (each pack at the split current must clear ALL):")
	56	limits = [("JK-BMS OCP trip (300s)", bms_trip),
	57	("EVE cell-honest (0.5P)", cell_cont),
	58	("JK-BMS marketed max", bms_market)]
	59	pack_binding = min(limits, key=lambda x: x[1])
	60	for name, lim in limits:
	61	result(f" vs {name}", f"{i_pack:.1f} / {lim:.0f}", "A",
	62	f"{'PASS' if i_pack <= lim else 'FAIL'} ({100*i_pack/lim:.0f}%)")
	63	result(" per-pack binding", f"{pack_binding[0]} = {pack_binding[1]:.0f} A", "",
	64	f"headroom {pack_binding[1]-i_pack:.0f}A ({100*(pack_binding[1]-i_pack)/pack_binding[1]:.0f}%)")
	65
	66	c_dis = i_pack / cap_ah
	67	c_chg = (inv_chg / npack) / cap_ah
	68	result("per-pack discharge C-rate", f"{c_dis:.2f}C", "", f"{i_pack:.1f}A / {cap_ah}Ah (<=0.5C OK)")
	69	result("per-pack charge C-rate", f"{c_chg:.2f}C", "", f"{inv_chg/npack:.0f}A/pack at the {inv_chg}A bank charge max")
	70
	71	print("\n Surge transient (18kPV peak is MINUTES — check per-pack vs the 150A/300s BMS OCP):")
	72	i_surge_bank = surge_nopv / eff / vnom
	73	i_surge_pack = i_surge_bank / npack
	74	result(" battery-only surge (w/o PV, 10min)", f"{surge_nopv}W -> bank {i_surge_bank:.0f}A",
	75	"", f"inverter caps draw at {inv_dis}A")
	76	result(" per-pack surge current", round(i_surge_pack, 1), "A",
	77	f"vs BMS OCP {bms_trip}A/{bms_delay}s: {'UNDER -> no trip' if i_surge_pack < bms_trip else 'OVER -> would trip'}")
	78	result(" w/ PV peak (5min)", f"{surge_pv}W", "", "PV contributes -> battery share <= the w/o-PV case")
	79	surge_note = (f"{npack}-pack split keeps per-pack surge {i_surge_pack:.0f}A under the "
	80	f"{bms_trip}A/{bms_delay}s BMS OCP even over the 18kPV's 10-min peak window "
	81	f"(the single-pack Phase-1 case relied on the 3.5s 6000XP surge being too brief).")
	82
	83	load = load_result("08_load_actual")
	84	bank_kwh = usable_kwh * npack
	85	bank_dod = bank_kwh * dod
	86	avg = load["daily_avg_kwh"]; peak = load["august_peak_kwh_day"]
	87	print(f"\n Autonomy ({npack} packs = {bank_kwh:.1f} kWh nameplate / {bank_dod:.1f} kWh @ {dod*100:.0f}% DoD):")
	88	result(" runtime @ 12kW (100%/80%)", f"{bank_kwh/12:.2f} / {bank_dod/12:.2f}", "h")
	89	result(" days @ avg load", round(bank_dod/avg, 2), "days", f"{avg} kWh/day (Hardwick)")
	90	result(" days @ Aug peak", round(bank_dod/peak, 2), "days", f"{peak} kWh/day; generator backfills deeper")
	91
	92	print("\n Class-T fusing (per-pack = primary OCP; NEC 240.6 / 690.9 / 480.9):")
	93	req_pack = i_pack * 1.25
	94	pca = pack_cable["final_gauge_AWG"]; pamp = T310_16[pca][1]
	95	pack_fuse = std_ocpd_at_least(req_pack)
	96	ok_pack = pack_fuse <= pamp
	97	result(" per-pack required (125% x cont)", round(req_pack, 1), "A")
	98	result(" per-pack Class-T", f"{pack_fuse} A", "",
	99	f"<= {pca} cable {pamp}A ({'OK' if ok_pack else 'UPSIZE CABLE'}); DC-rated 20kAIC")
	100	result(" bank aggregate (Npack x pack fuse)", f"{npack*pack_fuse} A", "",
	101	f"bank conductor must carry this: 2x2/0=350A or 500kcmil=380A coordinate")
	102	result(" fuse vs BMS SC trip", f"{pack_fuse}A << {bms_sc}A SC / 20kAIC", "",
	103	"layered: per-pack BMS protects cells, Class-T protects each pack cable + fault current")
	104
	105	verdict = i_bank <= inv_dis and i_pack <= pack_binding[1] and ok_pack
	106	result("OVERALL battery verdict", "PASS" if verdict else "REVIEW")
	107
	108	dump_result("04_battery" + suffix(cfg), {
	109	"phase": "phase2", "pack_count": npack,
	110	"bank_discharge_A_12kW": round(i_bank, 1), "bank_demand_A": round(i_bank_demand, 1),
	111	"per_pack_discharge_A": round(i_pack, 1),
	112	"bank_limit": {"name": "inverter max discharge", "A": inv_dis,
	113	"headroom_A": round(inv_dis - i_bank, 1)},
	114	"per_pack_limits_A": {n: round(l, 0) for n, l in limits},
	115	"per_pack_binding": {"name": pack_binding[0], "A": round(pack_binding[1], 0),
	116	"headroom_A": round(pack_binding[1] - i_pack, 1)},
	117	"per_pack_discharge_C": round(c_dis, 3), "per_pack_charge_C": round(c_chg, 3),
	118	"surge_bank_A": round(i_surge_bank, 1), "surge_per_pack_A": round(i_surge_pack, 1),
	119	"surge_note": surge_note,
	120	"bank_usable_kwh": round(bank_kwh, 2), "bank_usable_kwh_80dod": round(bank_dod, 2),
	121	"runtime_12kw_80dod_h": round(bank_dod/12, 2),
	122	"days_at_avg_load": round(bank_dod/avg, 2), "days_at_aug_peak": round(bank_dod/peak, 2),
	123	"per_pack_classT_fuse_A": pack_fuse, "per_pack_cable_AWG": pca,
	124	"per_pack_cable_ampacity_A": pamp, "bank_aggregate_fuse_A": npack*pack_fuse,
	125	"bank_cable_single_AWG": bank_cable["final_gauge_AWG"],
	126	"fuse_cable_ok": ok_pack, "verdict": "PASS" if verdict else "REVIEW",
	127	"comms_note": ("2 packs: JK-BMS master/slave, one master -> 18kPV via CAN (single link). "
	128	"18kPV native closed-loop is EG4-48V; Docan/JK via a CAN profile — confirm on "
	129	"arrival. Open-loop fallback fully viable (no battery-life penalty)."),
	130	})
	131
	132
	133	def main():
	134	ap = argparse.ArgumentParser()
	135	ap.add_argument("--phase2", action="store_true",
	136	help="final state: 2x Docan S3 bank on the EG4 18kPV")
	137	args = ap.parse_args()
	138	cfg = load_site(phase2=args.phase2)
	139	if is_phase2(cfg):
	140	phase2_battery(cfg)
	141	return
	142	banner("04 BATTERY (discharge current, C-rate, runtime, Class-T fuse)")
	143	cond = load_result("03_conductors")["battery"]
	144
	145	vnom = require(cfg, "battery.nominal_v")
	146	cap_ah = require(cfg, "battery.capacity_ah")
	147	usable_kwh = require(cfg, "battery.usable_kwh")
	148	dod = require(cfg, "battery.dod_design")
	149	ac_w = require(cfg, "inverter.ac_continuous_w")
	150	surge_w = require(cfg, "inverter.ac_surge_w")
	151	eff = require(cfg, "inverter.discharge_eff")
	152
	153	inv_dis = require(cfg, "inverter.batt_max_discharge_a")
	154	inv_chg = require(cfg, "inverter.batt_max_charge_a")
	155	bms_trip = require(cfg, "battery.bms_discharge_ocp_a")
	156	bms_trip_delay = require(cfg, "battery.bms_ocp_delay_s")
	157	bms_sc = require(cfg, "battery.bms_short_circuit_a")
	158	bms_market = require(cfg, "battery.bms_continuous_a")
	159	cell_cont = require(cfg, "battery.cell_continuous_a")
	160
	161	# --- continuous discharge @ full AC ---
	162	i_dis = ac_w / eff / vnom
	163	result("inverter AC continuous", ac_w, "W")
	164	result("battery discharge current", round(i_dis, 1), "A", "ac_w/eff/Vnom @ 6kW")
	165	print("\n Limit stack (continuous discharge must clear ALL):")
	166	limits = [("inverter max discharge", inv_dis),
	167	("JK-BMS OCP trip (300s)", bms_trip),
	168	("EVE cell-honest (0.5P)", cell_cont),
	169	("JK-BMS marketed max", bms_market)]
	170	binding = min(limits, key=lambda x: x[1])
	171	for name, lim in limits:
	172	result(f" vs {name}", f"{round(i_dis,1)} / {lim}", "A",
	173	f"{'PASS' if i_dis <= lim else 'FAIL'} ({100*i_dis/lim:.0f}%)")
	174	result("binding limit", f"{binding[0]} = {binding[1]} A", "",
	175	f"headroom {binding[1]-i_dis:.0f} A ({100*(binding[1]-i_dis)/binding[1]:.0f}%)")
	176
	177	# --- C-rate ---
	178	c_dis = i_dis / cap_ah
	179	c_chg_pv = inv_chg / cap_ah
	180	result("discharge C-rate", f"{c_dis:.2f}C", "", f"{round(i_dis,1)}A / {cap_ah}Ah (<=0.5C OK)")
	181	result("charge C-rate (PV max)", f"{c_chg_pv:.2f}C", "", f"{inv_chg}A / {cap_ah}Ah")
	182
	183	# --- surge transient ---
	184	i_surge = surge_w / eff / vnom
	185	print("\n Surge transient (inverter peak ~3.5 s):")
	186	result(" battery surge current", round(i_surge, 1), "A", f"{surge_w}W/eff/Vnom")
	187	result(" vs JK-BMS short-circuit", f"{round(i_surge,1)} / {bms_sc}", "A",
	188	f"{'under SC trip' if i_surge < bms_sc else 'OVER'} (3.5s << relevant)")
	189	result(" vs JK-BMS OCP trip", f"{round(i_surge,1)} > {bms_trip}", "A",
	190	f"but OCP delay {bms_trip_delay}s >> 3.5s -> no nuisance trip")
	191	surge_note = ("transient only; one pack cannot sustain >6kW continuously — "
	192	"Phase-2 second pack relieves surge headroom")
	193
	194	# --- runtime sanity ---
	195	print("\n Runtime (sanity — winter off-grid still needs the generator):")
	196	rt_full = usable_kwh / (ac_w / 1000.0)
	197	rt_full_dod = usable_kwh * dod / (ac_w / 1000.0)
	198	rt_avg_dod = usable_kwh * dod / 1.5
	199	result(" @ full 6kW (100% / 80% DoD)", f"{rt_full:.2f} / {rt_full_dod:.2f}", "h")
	200	result(" @ 1.5kW avg load (80% DoD)", f"{rt_avg_dod:.1f}", "h")
	201
	202	# --- Class-T fuse final ---
	203	print("\n Class-T fuse selection (NEC 240.6 / 690.9 / 480.9):")
	204	req = i_dis * 1.25
	205	cable_awg = cond["final_gauge_AWG"]
	206	cable_amp = T310_16[cable_awg][1]
	207	fuse = std_ocpd_at_least(req)
	208	# fuse must be <= cable ampacity
	209	ok_cable = fuse <= cable_amp
	210	result(" required (125% x cont)", round(req, 1), "A", "240.6 next size up")
	211	result(" Class-T fuse", f"{fuse} A", "", "DC-rated, 20 kAIC")
	212	result(" cable coordination", f"{fuse}A <= {cable_awg} ampacity {cable_amp}A",
	213	"", "OK" if ok_cable else "UPSIZE CABLE")
	214	result(" fuse vs BMS SC trip", f"{fuse}A < {bms_sc}A SC / interrupt 20kAIC",
	215	"", "layered: BMS protects cells, fuse protects cable + fault current")
	216
	217	verdict = i_dis <= binding[1] and ok_cable
	218	result("OVERALL battery verdict", "PASS" if verdict else "REVIEW")
	219
	220	dump_result("04_battery", {
	221	"discharge_A_6kW": round(i_dis, 1),
	222	"limits_A": {n: l for n, l in limits},
	223	"binding_limit": {"name": binding[0], "A": binding[1],
	224	"headroom_A": round(binding[1] - i_dis, 1)},
	225	"discharge_C": round(c_dis, 3), "charge_C_pv": round(c_chg_pv, 3),
	226	"surge_A": round(i_surge, 1), "surge_note": surge_note,
	227	"runtime_full_h": round(rt_full, 2), "runtime_full_80dod_h": round(rt_full_dod, 2),
	228	"runtime_1p5kw_80dod_h": round(rt_avg_dod, 1),
	229	"classT_fuse_A": fuse, "cable_AWG": cable_awg, "cable_ampacity_A": cable_amp,
	230	"fuse_cable_ok": ok_cable, "verdict": "PASS" if verdict else "REVIEW",
	231	})
	232
	233
	234	if __name__ == "__main__":
	235	main()

scripts/05_nec_checklist.py +225 -0

…	…	@@ -0,0 +1,225 @@
	1	"""05 — NEC Article 690 + 480/706/710 checklist with COMPUTED evidence.
	2
	3	Pulls the load-bearing numbers from scripts 01/03/04 results so each pass/fail
	4	cites a computed value, not an estimate. Off-grid stand-alone, NEC 2023.
	5
	6	Run (after 01/03/04): ~/.venvs/prsm-electrical/bin/python scripts/05_nec_checklist.py
	7	"""
	8	import argparse
	9	from common import load_site, require, banner, dump_result, load_result, is_phase2, suffix
	10
	11
	12	def render(checks, nec):
	13	width = max(len(c["section"]) for c in checks)
	14	print(f"\n {'SECTION':<{width}} {'STATUS':<11} TOPIC")
	15	print(" " + "-" * 70)
	16	for c in checks:
	17	print(f" {c['section']:<{width}} {c['status']:<11} {c['topic']}")
	18	print(f" {'':<{width}} {'':<11} -> {c['evidence']}")
	19	print("\n " + "-" * 70)
	20	summary = {}
	21	for c in checks:
	22	summary[c["status"]] = summary.get(c["status"], 0) + 1
	23	print(" Summary: " + ", ".join(f"{k}={v}" for k, v in sorted(summary.items())))
	24	return summary
	25
	26
	27	def phase2_checklist(cfg):
	28	banner("05 NEC 690 + 480/705/706/710 CHECKLIST [PHASE 2 — EG4 18kPV, 2-pack ESS]")
	29	s01 = load_result("01_string_phase2")
	30	s03 = load_result("03_conductors_phase2")
	31	s04 = load_result("04_battery_phase2")
	32	pv = s03["pv_string"]; ac = s03["ac_output"]
	33	pk = s03["battery_per_pack"]; bk = s03["battery_bank"]
	34	nec = cfg["site"]["nec_cycle"]
	35	npack = int(require(cfg, "battery.pack_count"))
	36	checks = []
	37
	38	def add(sec, topic, status, evidence):
	39	checks.append({"section": sec, "topic": topic, "status": status, "evidence": evidence})
	40
	41	add("690.7", "Max system voltage (cold Voc)", "PASS",
	42	f"Longest string {s01['max_string_series']}S cold Voc {s01['string_cold_voc_V']} V "
	43	f"<= {s01['inv_design_ceiling_V']} V MPPT-fault / {s01['inv_abs_ceiling_V']} V abs "
	44	f"(margin {s01['margin_to_design_V']} V to fault, {s01['margin_to_abs_V']} V to abs). "
	45	f"Tmin {s01['tmin_C']}C; analytic+pvlib+vocmax+independent agent agree. 9S=553V REJECTED (>550).")
	46	add("690.8(A)", "Max circuit current", "PASS",
	47	f"Per string Isc x1.25 = {round(s01['string_isc_A']*1.25,1)} A (each string a dedicated "
	48	f"homerun). MPPT1 internally combines 2 strings = {round(2*s01['string_isc_A'],1)} A actual "
	49	f"<= 31 A MPPT1 Isc rating; MPPT2/3 single string <= 19 A.")
	50	add("690.8(B)", "Conductor ampacity after 310.15 derates", "PASS",
	51	f"PV {pv['final_gauge_AWG']}Cu derated {pv['ampacity_derated90_A']}A >= {pv['req_ampacity_derated_A']}A "
	52	f"(8 CCC, 0.70 fill); AC {ac['final_gauge_AWG']}Cu; per-pack {pk['final_gauge_AWG']}Cu; "
	53	f"bank {bk['final_gauge_AWG']}kcmil (or 2x2/0 / 2x4/0).")
	54	add("690.9 / 690.9(A) Ex", "PV source-circuit overcurrent (fusing)", "PASS",
	55	f"NOT required: MPPT1 parallels only 2 strings -> max backfeed 1.25xIsc="
	56	f"{pv['parallel_backfeed_A']}A <= module {require(cfg,'panel.series_fuse_a')}A series fuse "
	57	f"(3+ parallel strings would require fuses). MPPT2/3 single string. No combiner.")
	58	add("690.9 / 240 / 480.9", "Battery overcurrent (per-pack Class-T)", "PASS",
	59	f"{npack}x {s04['per_pack_classT_fuse_A']}A Class-T (DC, 20kAIC), one per pack, "
	60	f">= 125% x {s04['per_pack_discharge_A']}A/pack; <= {pk['final_gauge_AWG']} cable "
	61	f"{s04['per_pack_cable_ampacity_A']}A. Bank aggregate {s04['bank_aggregate_fuse_A']}A "
	62	f"coordinated with the bank conductor.")
	63	add("690.9 / 710.15", "Inverter AC output overcurrent", "PASS",
	64	f"{ac['ocpd_A']}A 2-pole >= 125% x {ac['current_A']}A; protects {ac['final_gauge_AWG']}Cu "
	65	f"(240.4(D)); EGC {ac['egc_AWG']}AWG.")
	66	add("690.11", "DC arc-fault (AFCI)", "PASS",
	67	"EG4 18kPV integrated PV AFCI (690.11 / UL1699B, per datasheet).")
	68	add("690.12", "Rapid shutdown", "VERIFY-AHJ",
	69	f"18kPV has an integrated RSD initiator (datasheet cites NEC 2020:690.12). Detached "
	70	f"ground-mount (not on a building) is likely exempt, but PV/DC conductors enter the dwelling "
	71	f"-> confirm the VT DPS inspector's stance for NEC {nec}. Initiator present if required.")
	72	add("690.13 / 690.15", "PV + equipment disconnects", "PASS",
	73	f"18kPV integrated PV disconnect; add an external load-break DC/PV disconnect for service. "
	74	f"Battery: {npack} per-pack disconnects + a {s04['bank_discharge_A_12kW']:.0f}A-class bank "
	75	f"disconnect within sight of the inverter.")
	76	add("690.41(B)", "System grounding / GFDI", "PASS",
	77	"18kPV integrated PV ground-fault monitoring (690.41(B)) + pole-sensitive leakage-current "
	78	"monitor + integrated SPD (per datasheet).")
	79	add("690.43 / 690.45", "Equipment grounding & EGC size (250.122)", "PASS",
	80	f"EGCs: PV 10AWG (no source OCPD), per-pack {pk['egc_AWG']}AWG ({pk['ocpd_A']}A), "
	81	f"AC {ac['egc_AWG']}AWG ({ac['ocpd_A']}A), bank 4AWG (sized to disconnect). Bond all array "
	82	f"frames + enclosures + the battery busbar.")
	83	add("690.47", "Grounding electrode (array + DC)", "ACTION",
	84	"Ground-mount: drive an array grounding electrode (rod), 6AWG Cu GEC bonded to the dwelling "
	85	"GES (690.47(A)). Carries forward from Phase 1; verify for the expanded array footprint.")
	86	add("690.31", "Wiring methods", "PASS",
	87	f"PV in Sched-40 PVC conduit (squirrel/UV, Swarm §16); {pv['final_gauge_AWG']}Cu THWN-2/PV "
	88	f"90C. {s01['n_strings']} strings -> split across 2 conduits to relax the 8-CCC fill.")
	89	add("705", "Interconnection (utility)", "N/A",
	90	"Off-grid, no utility interconnection (no 705.12 backfeed limit). Generator AC-IN to the "
	91	"18kPV (200A AC bypass / 90A gen) with the main panel subfed and its main breaker locked "
	92	"off (Swarm §17); transfer is internal to the hybrid inverter.")
	93	add("706.7 / 706.20", "ESS — multi-pack arrangement & control", "PASS",
	94	f"{npack}x Docan S3 (LFP, JK-PB2A16S20P BMS) in parallel on a DC busbar. Each pack has its "
	95	f"own BMS + Class-T + disconnect. Bank discharge {s04['bank_discharge_A_12kW']:.0f}A split "
	96	f"{s04['per_pack_discharge_A']}A/pack — within the 150A/300s JK OCP (17% headroom) and the "
	97	f"157A EVE-cell limit. C-rate {s04['per_pack_discharge_C']}C.")
	98	add("706.30 / 480.7", "ESS disconnecting means", "PASS",
	99	"Per-pack disconnects + a bank disconnect (lockable, within sight of the ESS); the 18kPV "
	100	"battery port is the inverter-side disconnect. BMS opens on cell-level faults.")
	101	add("706.31 / 480.9", "ESS overcurrent protection", "PASS",
	102	f"Per-pack {s04['per_pack_classT_fuse_A']}A Class-T (20kAIC > pack prospective fault). "
	103	f"Layered: JK-BMS (150A/300s OCP, 300A SC) protects cells; Class-T protects each pack cable.")
	104	add("706.x / BMS comms", "Multi-pack BMS communications", "VERIFY",
	105	"2 packs: JK-BMS master/slave, one master -> 18kPV via CAN (a SINGLE comms link, vs 2 for a "
	106	"parallel-6000XP path). 18kPV native closed-loop is EG4-48V; the Docan/JK pack runs via a CAN "
	107	"profile -> confirm on arrival. Open-loop fallback fully viable (no battery-life penalty).")
	108	add("710.15", "Stand-alone system output", "PASS",
	109	f"18kPV 12kW 120/240V split-phase, output {ac['current_A']}A; off-grid, no utility backfeed. "
	110	f"Continuous line 8000W/120V leg covers the household peak; surge 13.5kW (w/o PV).")
	111	add("690.53/54/56 / 110.21", "Labels & placards", "ACTION",
	112	f"Max system voltage {s01['string_cold_voc_V']}V (690.53), inverter output 12kW/{ac['current_A']:.0f}A "
	113	f"(690.54), RSD placard if AHJ requires (690.56(C)), DC disconnect + directory, per-pack battery "
	114	f"hazard labels. Generate from these computed ratings.")
	115	add("NFPA 855 / VT 2025 Fire Code", "ESS fire code (OUT OF SCOPE — GATE)", "FLAG",
	116	f"{npack} packs = {round(require(cfg,'battery.usable_kwh')*npack,1)}kWh nameplate. Swarm §4: even "
	117	f"2 packs (32kWh) likely crosses the 20kWh residential threshold (3 packs/48kWh definitively) -> "
	118	f"detached non-combustible shed >=10ft, UL9540 listing or AHJ hazard-mitigation analysis, + "
	119	f"propane-heater combustion-air/ventilation/separation. NOT engineered here — pre-clear with VT "
	120	f"DPS in writing before ordering the 2nd pack.")
	121	add("Voltage drop (design target)", "DC<=2% / batt<=1% / AC<=2%", "PASS",
	122	f"DC {pv['vdrop_pct']}% (150-250ft: {pv.get('vdrop_sweep_pct')}); per-pack {pk['vdrop_pct']}%; "
	123	f"bank {bk['vdrop_pct']}%; AC {ac['vdrop_pct']}%. (Informational; not NEC-mandated.)")
	124
	125	summary = render(checks, nec)
	126	dump_result("05_checklist" + suffix(cfg),
	127	{"phase": "phase2", "nec_cycle": nec, "checks": checks, "summary": summary})
	128
	129
	130	def main():
	131	ap = argparse.ArgumentParser()
	132	ap.add_argument("--phase2", action="store_true", help="final-state checklist (EG4 18kPV, 2-pack ESS)")
	133	args = ap.parse_args()
	134	cfg = load_site(phase2=args.phase2)
	135	if is_phase2(cfg):
	136	phase2_checklist(cfg)
	137	return
	138	banner("05 NEC 690 + 480/706/710 CHECKLIST (NEC 2023, off-grid)")
	139	s01 = load_result("01_string")
	140	s03 = load_result("03_conductors")
	141	s04 = load_result("04_battery")
	142
	143	pv = s03["pv_string"]; bat = s03["battery"]; ac = s03["ac_output"]
	144	nec = cfg["site"]["nec_cycle"]
	145
	146	checks = []
	147
	148	def add(sec, topic, status, evidence):
	149	checks.append({"section": sec, "topic": topic, "status": status,
	150	"evidence": evidence})
	151
	152	add("690.7", "Max system voltage (cold Voc)", "PASS",
	153	f"{s01['n_series']}S cold Voc {s01['string_cold_voc_V']} V <= {s01['inv_design_ceiling_V']} V "
	154	f"design / {s01['inv_abs_ceiling_V']} V abs (margin {s01['margin_to_500_V']} V). "
	155	f"Tmin {s01['tmin_C']}C; analytic+pvlib agree.")
	156	add("690.8(A)", "Max circuit current (Isc x 1.25)", "PASS",
	157	f"PV source max current {round(s01['string_isc_A']*1.25,1)} A (Isc {s01['string_isc_A']} x 1.25).")
	158	add("690.8(B)", "Conductor ampacity after 310.15 derates", "PASS",
	159	f"PV string {pv['final_gauge_AWG']} Cu: 75C {pv['ampacity_75C_A']}A, derated "
	160	f"{pv['ampacity_derated90_A']}A >= req {pv['req_ampacity_derated_A']}A.")
	161	add("690.9 / 690.9(A) Ex", "PV source overcurrent (string fusing)", "PASS",
	162	"Not required: 1 string per MPPT (no parallel strings), so no source-circuit "
	163	"fault current can exceed module 30A series-fuse rating. Each MPPT isolated.")
	164	add("690.9 / 240 / 480.9", "Battery overcurrent (Class-T)", "PASS",
	165	f"{s04['classT_fuse_A']}A Class-T (DC, 20kAIC) >= 125%x{s04['discharge_A_6kW']}A; "
	166	f"<= cable {s04['cable_AWG']} ampacity {s04['cable_ampacity_A']}A.")
	167	add("690.9 / 710.15", "Inverter AC output overcurrent", "PASS",
	168	f"{ac['ocpd_A']}A 2-pole >= 125% x {ac['current_A']}A; protects {ac['final_gauge_AWG']} Cu (240.4(D)).")
	169	add("690.12", "Rapid shutdown", "VERIFY-AHJ",
	170	f"Ground-mounted array NOT on a building: 690.12 (NEC {nec}) applies to PV on/in "
	171	"buildings. 6000XP has a built-in RSD initiator if AHJ requires it for conductors "
	172	"entering the dwelling. Confirm AHJ stance for the detached ground-mount.")
	173	add("690.13", "PV disconnecting means", "PASS",
	174	"6000XP integrated DC switch per MPPT; add an external load-break PV/DC disconnect "
	175	"at the inverter for service isolation.")
	176	add("690.15", "Disconnect for equipment", "PASS",
	177	"Battery disconnect (switch or the Class-T fused disconnect) within sight of inverter.")
	178	add("690.11 / 690.41", "DC arc-fault + system grounding (GFDI)", "PASS",
	179	"6000XP integrated PV AFCI (690.11) and PV ground-fault/isolation protection (690.41/690.5).")
	180	add("690.43", "Equipment grounding & bonding", "PASS",
	181	f"EGCs: PV {pv.get('egc_AWG') or '10'} / battery {bat['egc_AWG']} / AC {ac['egc_AWG']} AWG Cu; "
	182	"bond array frames + all enclosures.")
	183	add("690.45", "Size of EGC (250.122)", "PASS",
	184	f"Battery EGC {bat['egc_AWG']} AWG (OCPD {bat['ocpd_A']}A); AC EGC {ac['egc_AWG']} AWG "
	185	f"(OCPD {ac['ocpd_A']}A); PV EGC min 10 AWG (no source OCPD).")
	186	add("690.47", "Grounding electrode (array + DC)", "ACTION",
	187	"Ground-mount: drive an array grounding electrode (rod) and bond per 690.47(A); "
	188	"min 6 AWG Cu GEC, common with the dwelling grounding electrode system.")
	189	add("690.31", "Wiring methods", "PASS",
	190	f"PV in conduit (Sched-40 PVC, squirrel/UV protection per Swarm §16); {pv['final_gauge_AWG']} Cu PV wire/THWN-2 90C.")
	191	add("706.30 / 480.7", "ESS disconnecting means", "PASS",
	192	"Battery disconnect + Class-T fuse; lockable; within sight of the ESS.")
	193	add("706.31 / 480.9", "ESS overcurrent protection", "PASS",
	194	f"{s04['classT_fuse_A']}A Class-T at the battery positive, interrupt 20kAIC > pack fault current.")
	195	add("710.15", "Stand-alone system output", "PASS",
	196	f"6000XP 6kW 120/240 split-phase; output {ac['current_A']}A; no utility backfeed (off-grid).")
	197	add("705", "Interconnection (120% / backfeed)", "N/A",
	198	"Off-grid, no utility interconnection. Main panel subfed with main breaker locked off (Swarm §17).")
	199	add("690.53/690.54/690.56/110.21", "Labels & placards", "ACTION",
	200	"Required: max system voltage (690.53), inverter output rating (690.54), "
	201	"rapid-shutdown placard if applicable (690.56(C)), DC disconnect & directory, "
	202	"battery hazard label. Generate per the computed ratings.")
	203	add("Voltage drop (design target)", "DC<=2% / batt<=1% / AC<=2%", "PASS",
	204	f"DC {pv['vdrop_pct']}% (150-250ft: {pv.get('vdrop_sweep_pct')}); "
	205	f"battery {bat['vdrop_pct']}%; AC {ac['vdrop_pct']}%. (Informational; not NEC-mandated.)")
	206
	207	# print
	208	width = max(len(c["section"]) for c in checks)
	209	npass = sum(1 for c in checks if c["status"] == "PASS")
	210	print(f"\n {'SECTION':<{width}} {'STATUS':<11} TOPIC")
	211	print(" " + "-" * 70)
	212	for c in checks:
	213	print(f" {c['section']:<{width}} {c['status']:<11} {c['topic']}")
	214	print(f" {'':<{width}} {'':<11} -> {c['evidence']}")
	215	print("\n " + "-" * 70)
	216	summary = {}
	217	for c in checks:
	218	summary[c["status"]] = summary.get(c["status"], 0) + 1
	219	print(f" Summary: " + ", ".join(f"{k}={v}" for k, v in sorted(summary.items())))
	220
	221	dump_result("05_checklist", {"nec_cycle": nec, "checks": checks, "summary": summary})
	222
	223
	224	if __name__ == "__main__":
	225	main()

scripts/06_schematics.py +480 -0

…	…	@@ -0,0 +1,480 @@
	1	"""06 — Schematic renderings (schemdraw -> PNG + SVG into artifacts/).
	2
	3	Three drawings, every rating pulled from the COMPUTED result JSONs (01/03/04) so
	4	the gauge/fuse on the page equals what the calc produced:
	5	sld.(png|svg) system single-line
	6	dc-strings.(png|svg) module-level string grouping across the 2 MPPTs
	7	battery-wiring.(png|svg) 6000XP <-> Docan S3 with Class-T fuse + BMS comms
	8
	9	Run (after 01/03/04): ~/.venvs/prsm-electrical/bin/python scripts/06_schematics.py
	10	"""
	11	import argparse
	12	import pathlib
	13	import schemdraw
	14	from schemdraw import elements as elm
	15	from common import load_site, banner, load_result, require, is_phase2
	16
	17	schemdraw.use("matplotlib")
	18	ART = pathlib.Path(__file__).resolve().parent.parent / "artifacts"
	19	# Owner selected PATH A (2x 6000XP) on 2026-06-03 -> it is the primary `phase2/` deliverable.
	20	# Path B (18kPV) is retained as the documented alternative in `phase2-pathB/`.
	21	ART_P2 = ART / "phase2-pathB" # Path B = retained alternative
	22	CAP = "PRSM OFF-GRID PV · NEK Vermont · NEC 2023 · ratings trace to scripts 01/03/04"
	23	CAP_P2 = "PRSM OFF-GRID PV — PATH B / 18kPV (RETAINED ALTERNATIVE) · NEK Vermont · NEC 2023 · ratings trace to scripts 01/03/04"
	24
	25
	26	def save(d, name, art=ART):
	27	art.mkdir(parents=True, exist_ok=True)
	28	d.save(str(art / f"{name}.svg"))
	29	d.save(str(art / f"{name}.png"), dpi=200)
	30	print(f" rendered {art.name}/{name}.svg + .png")
	31
	32
	33	def title(d, text, xy, size=13):
	34	d += elm.Label().label(text, fontsize=size).at(xy)
	35
	36
	37	def sld(cfg, s01, s03, s04):
	38	pv, bat, ac = s03["pv_string"], s03["battery"], s03["ac_output"]
	39	ukwh = require(cfg, "battery.usable_kwh")
	40	d = schemdraw.Drawing()
	41	d.config(fontsize=10, unit=2.6)
	42
	43	# --- main spine ---
	44	d += elm.Solar().right().label(
	45	f"PV ARRAY\n14×575W · 2×{s01['n_series']}S\n{s01['array_dc_W']}W DC\n"
	46	f"cold Voc {s01['string_cold_voc_V']}V", loc="bottom")
	47	d += elm.Line().right().length(2.4).label(
	48	f"{pv['final_gauge_AWG']}AWG·{pv['length_ft']}ft\n{pv['vdrop_pct']}%", loc="top")
	49	d += elm.SwitchDpst().right().label("DC\ndisc", loc="bottom")
	50	d += elm.Line().right().length(1.0)
	51	inv = d.add(elm.Ic(pins=[
	52	elm.IcPin(name="PV", side="left"),
	53	elm.IcPin(name="AC", side="right"),
	54	elm.IcPin(name="BATP", side="bottom", slot="1/4"),
	55	elm.IcPin(name="GND", side="bottom", slot="4/4"),
	56	], w=5.2, h=4.4).label(
	57	"EG4 6000XP\n6kW 120/240V\ndual MPPT\nRSD·AFCI·GFDI", loc="center", fontsize=10
	58	).anchor("PV"))
	59
	60	# --- AC branch ---
	61	d += elm.Line().right().length(1.6).at(inv.AC)
	62	d += elm.SwitchDpst().right().label(f"{ac['ocpd_A']}A\n2-pole", loc="top")
	63	d += elm.Line().right().length(0.6)
	64	d += elm.RBox(w=2.8, h=2.2).label(
	65	f"MAIN PANEL\nsubfed\n{ac['final_gauge_AWG']}AWG·{ac['length_ft']}ft", fontsize=9)
	66
	67	# --- battery branch (down from BATP, far-left bottom pin) ---
	68	d += elm.Line().down().length(1.4).at(inv.BATP)
	69	d += elm.Fuse().down().label(f"{s04['classT_fuse_A']}A Class-T", loc="left")
	70	d += elm.Line().down().length(0.5)
	71	d += elm.SwitchDpst().down().label("batt disc", loc="left")
	72	d += elm.Line().down().length(0.5)
	73	d += elm.Battery().down().label(
	74	f"Docan S3\n51.2V {ukwh}kWh\n{bat['final_gauge_AWG']}Cu·{bat['length_ft']}ft·{bat['vdrop_pct']}%",
	75	loc="left")
	76
	77	# --- ground branch (down from GND, far-right bottom pin) ---
	78	d += elm.Line().down().length(1.2).at(inv.GND)
	79	d += elm.Ground().label("GEC\n6AWG\n690.47", loc="right", fontsize=8)
	80
	81	cx, cy = inv.center
	82	title(d, "SINGLE-LINE DIAGRAM — PRSM OFF-GRID PV", (cx, cy + 4.2))
	83	d += elm.Label().label(CAP, fontsize=8).at((cx, cy + 3.3))
	84	save(d, "sld")
	85
	86
	87	def dc_strings(cfg, s01, s03):
	88	pv = s03["pv_string"]
	89	voc_cold = s01["string_cold_voc_V"]
	90	vmp = round(s01["n_series"] * require(cfg, "panel.vmp_v"))
	91	n = s01["n_series"]
	92	d = schemdraw.Drawing()
	93	d.config(fontsize=10, unit=1.15)
	94	for row, (yy, mppt) in enumerate([(0.0, "MPPT1"), (-3.0, "MPPT2")]):
	95	d += elm.Label().label(f"String {row+1}\n(+)", fontsize=9).at((-1.5, yy))
	96	d += elm.Solar().right().at((0, yy))
	97	for _ in range(n - 1):
	98	d += elm.Solar().right()
	99	d += elm.Line().right().length(0.9).label(f"{pv['final_gauge_AWG']}AWG", loc="top", fontsize=8)
	100	d += elm.RBox(w=1.6, h=1.5).label(f"{mppt}\nEG4", fontsize=9)
	101	title(d, f"DC STRING WIRING — 2 strings × {n}S across MPPT1 / MPPT2", (4.5, 1.9))
	102	d += elm.Label().label(
	103	f"Each string: {n}×Waaree 575W series · Vmp≈{vmp}V · cold Voc {voc_cold}V "
	104	f"(≤480V design / 500V abs)\nNO source-circuit fuse — one string per MPPT (690.9(A) Exc.) "
	105	f"· MAX 7 modules/string (8S = 491V, unsafe)", fontsize=8).at((4.5, -5.2))
	106	save(d, "dc-strings")
	107
	108
	109	def battery_wiring(cfg, s03, s04):
	110	bat = s03["battery"]
	111	ukwh = require(cfg, "battery.usable_kwh")
	112	d = schemdraw.Drawing()
	113	d.config(fontsize=10, unit=2.4)
	114	inv = d.add(elm.Ic(pins=[
	115	elm.IcPin(name="BATP", side="right", slot="3/3"),
	116	elm.IcPin(name="BATN", side="right", slot="1/3"),
	117	elm.IcPin(name="COM", side="bottom"),
	118	], w=3.0, h=3.2).label("EG4 6000XP\nBAT 46.4–60V\nmax 140A dis", loc="center", fontsize=9).at((0, 0)))
	119
	120	# positive path: BATP -> Class-T fuse -> disconnect -> battery top
	121	d += elm.Line().right().length(1.3).at(inv.BATP).label("+", loc="top")
	122	d += elm.Fuse().right().label(f"{s04['classT_fuse_A']}A\nClass-T", loc="top")
	123	d += elm.SwitchDpst().right().label("disc", loc="bottom")
	124	top = d.add(elm.Line().right().length(1.7))
	125	batt = d.add(elm.Battery().down().at(top.end).label(
	126	f"Docan S3\n51.2V·{ukwh}kWh\n16S1P · JK 200A BMS", loc="right", fontsize=9))
	127	# negative return
	128	d += elm.Line().left().at(batt.end).tox(inv.BATN[0]).label(
	129	f"− {bat['final_gauge_AWG']}Cu×{bat['length_ft']}ft·{bat['vdrop_pct']}%", loc="bottom", fontsize=9)
	130	d += elm.Line().up().toy(inv.BATN[1])
	131	# BMS comms (dashed)
	132	c = d.add(elm.Line(ls="--").down().length(1.6).at(inv.COM))
	133	d += elm.Line(ls="--").right().length(5.2).at(c.end).label(
	134	"JK BMS → Pylontech CAN → 6000XP 'Pylontech 2' (V19 fw)", loc="bottom", fontsize=8)
	135
	136	cx, cy = inv.center
	137	title(d, "BATTERY WIRING — EG4 6000XP ↔ Docan S3", (cx + 2.5, cy + 2.6))
	138	d += elm.Label().label(
	139	f"Discharge @6kW = {s04['discharge_A_6kW']}A (binding {s04['binding_limit']['name']} "
	140	f"{s04['binding_limit']['A']}A, {s04['binding_limit']['headroom_A']}A headroom) · "
	141	f"{s04['discharge_C']}C · recommend {bat.get('recommended_upsize_AWG','4/0')}Cu upsize",
	142	fontsize=8).at((cx + 2.0, cy - 4.2))
	143	save(d, "battery-wiring")
	144
	145
	146	def sld_p2(cfg, s01, s03, s04):
	147	"""Final-state single-line: 31-panel array -> 18kPV (3 MPPT) -> 2-pack bank + gen AC-IN."""
	148	pv, ac = s03["pv_string"], s03["ac_output"]
	149	pk, bk = s03["battery_per_pack"], s03["battery_bank"]
	150	npack = int(require(cfg, "battery.pack_count"))
	151	bank_dod = s04["bank_usable_kwh_80dod"] # usable @ 80% DoD (25.7), not nameplate
	152	d = schemdraw.Drawing()
	153	d.config(fontsize=10, unit=2.7)
	154
	155	d += elm.Solar().right().label(
	156	f"PV ARRAY\n31×575W · {s01['n_strings']} strings\n8+8+8+7S · {s01['array_dc_W']}W DC\n"
	157	f"cold Voc {s01['string_cold_voc_V']}V (≤550)", loc="bottom")
	158	d += elm.Line().right().length(2.6).label(
	159	f"{pv['final_gauge_AWG']}AWG×{pv['length_ft']}ft\n{pv['vdrop_pct']}% · 4 homeruns", loc="top")
	160	d += elm.SwitchDpst().right().label("DC\ndisc", loc="bottom")
	161	d += elm.Line().right().length(1.2)
	162	inv = d.add(elm.Ic(pins=[
	163	elm.IcPin(name="PV", side="left"),
	164	elm.IcPin(name="ACIN", side="top"),
	165	elm.IcPin(name="AC", side="right"),
	166	elm.IcPin(name="BATP", side="bottom", slot="1/4"),
	167	elm.IcPin(name="GND", side="bottom", slot="4/4"),
	168	], w=6.8, h=6.4).anchor("PV"))
	169	icx, icy = inv.center
	170	d += elm.Label().label("EG4 18kPV · 12kW 120/240V\n3 MPPT · 18kW PV · RSD·AFCI·GFDI",
	171	fontsize=9).at((icx, icy + 1.55))
	172
	173	# --- generator AC-IN (top) ---
	174	d += elm.Line().up().length(1.4).at(inv.ACIN)
	175	d += elm.SwitchDpst().up().label("gen AC-IN", loc="right", fontsize=9)
	176	d += elm.Line().up().length(0.6)
	177	d += elm.RBox(w=2.8, h=1.3).label("GENERATOR\n200A bypass · 90A gen", fontsize=8)
	178
	179	# --- AC branch ---
	180	d += elm.Line().right().length(1.8).at(inv.AC)
	181	d += elm.SwitchDpst().right().label(f"{ac['ocpd_A']}A\n2-pole", loc="top")
	182	d += elm.Line().right().length(1.3)
	183	d += elm.RBox(w=3.0, h=2.3).label(
	184	f"MAIN PANEL\nsubfed (main off)\n{ac['final_gauge_AWG']}AWG×{ac['length_ft']}ft", fontsize=9)
	185
	186	# --- battery branch (down from BATP): disc, then conductor label, busbar, fuse, packs ---
	187	d += elm.Line().down().length(0.9).at(inv.BATP)
	188	d += elm.SwitchDpst().down().label("bank disc 250A", loc="right", fontsize=8)
	189	d += elm.Line().down().length(1.5).label(
	190	f"bank {bk['final_gauge_AWG']}kcmil / 2×4/0\n×{bk['length_ft']}ft · {bk['current_A']:.0f}A · {bk['vdrop_pct']}%",
	191	loc="left", fontsize=8)
	192	d += elm.RBox(w=3.6, h=1.0).label("DC BUSBAR (250A)", fontsize=9)
	193	d += elm.Line().down().length(0.8)
	194	d += elm.Fuse().down().label(f"{npack}× {s04['per_pack_classT_fuse_A']}A Class-T", loc="right", fontsize=8)
	195	d += elm.Line().down().length(0.8)
	196	d += elm.Battery().down().label(
	197	f"{npack}× Docan S3 · 51.2V\n{bank_dod}kWh usable (80% DoD)\n{pk['final_gauge_AWG']}Cu/pack · "
	198	f"{pk['vdrop_pct']}% · JK-BMS→CAN", loc="left", fontsize=8)
	199
	200	# --- ground branch ---
	201	d += elm.Line().down().length(1.2).at(inv.GND)
	202	d += elm.Ground().label("GEC 6AWG\n690.47", loc="right", fontsize=8)
	203
	204	cx, cy = inv.center
	205	title(d, "FINAL-STATE SINGLE-LINE — PRSM OFF-GRID PV (Phase 2)", (cx, cy + 7.4))
	206	d += elm.Label().label(CAP_P2, fontsize=8).at((cx, cy + 6.7))
	207	save(d, "sld", ART_P2)
	208
	209
	210	def dc_strings_p2(cfg, s01, s03):
	211	"""Final-state DC strings: 4 strings (8+8+8+7S) across the 18kPV's 3 MPPTs (inputs 2/1/1)."""
	212	pv = s03["pv_string"]
	213	vmp_per = require(cfg, "panel.vmp_v")
	214	d = schemdraw.Drawing()
	215	d.config(fontsize=10, unit=1.4)
	216	# rows: (label, n_series, mppt-label, draw_mppt_box?)
	217	rows = []
	218	for e in s01["layout"]:
	219	for j, L in enumerate(e["lengths"]):
	220	rows.append((e["mppt"] + 1, L, j == 0, len(e["lengths"])))
	221	y = 0.0
	222	for i, (mppt, L, first_in_group, grp) in enumerate(rows):
	223	cold_voc = round(L * s01["voc_cold_module_V"], 0)
	224	vmp = round(L * vmp_per)
	225	d += elm.Label().label(f"String {i+1}\n{L}S (+)", fontsize=9).at((-1.7, y))
	226	d += elm.Solar().right().at((0, y)).label(f"{L}× Waaree 575W", loc="top", fontsize=8)
	227	d += elm.Line().right().length(1.0).label(f"{pv['final_gauge_AWG']}AWG", loc="top", fontsize=8)
	228	d += elm.Line().right().length(0.3).label(f"Vmp≈{vmp}V\ncoldVoc {cold_voc:.0f}V", loc="bottom", fontsize=8)
	229	d += elm.RBox(w=2.0, h=1.0).label(f"MPPT{mppt}\n18kPV" + (f"\n(2 strings)" if grp == 2 else ""),
	230	fontsize=9)
	231	y -= 1.8
	232	title(d, "FINAL-STATE DC STRINGS — 4 strings (8+8+8+7S) across 3 MPPTs", (2.6, 1.6))
	233	d += elm.Label().label(
	234	f"MPPT1 = 2×8S (paired) · MPPT2 = 8S · MPPT3 = 7S · 31 modules · {s01['array_dc_W']}W DC\n"
	235	f"MAX 8S: cold Voc 491.5V ≤ 550V fault / 600V abs\n"
	236	f"NO source fuse (≤2 parallel strings, backfeed {pv['parallel_backfeed_A']}A ≤ 30A module) · no combiner",
	237	fontsize=8).at((2.6, y - 0.5))
	238	save(d, "dc-strings", ART_P2)
	239
	240
	241	def battery_wiring_p2(cfg, s03, s04):
	242	"""Final-state battery: 18kPV ↔ DC busbar ↔ 2× Docan S3, per-pack Class-T + disconnect."""
	243	pk, bk = s03["battery_per_pack"], s03["battery_bank"]
	244	npack = int(require(cfg, "battery.pack_count"))
	245	ukwh = require(cfg, "battery.usable_kwh")
	246	d = schemdraw.Drawing()
	247	d.config(fontsize=10, unit=2.2)
	248	inv = d.add(elm.Ic(pins=[
	249	elm.IcPin(name="BATP", side="right", slot="3/3"),
	250	elm.IcPin(name="BATN", side="right", slot="1/3"),
	251	elm.IcPin(name="COM", side="bottom"),
	252	], w=3.0, h=3.4).label("EG4 18kPV\nBAT 40–60V\nmax 250A", loc="center", fontsize=9).at((0, 0)))
	253
	254	# BATP -> bank disconnect -> busbar
	255	d += elm.Line().right().length(1.2).at(inv.BATP).label("+", loc="top")
	256	d += elm.SwitchDpst().right().label("bank\ndisc", loc="top", fontsize=8)
	257	d += elm.Line().right().length(0.5).label(
	258	f"{bk['final_gauge_AWG']}kcmil\nor 2×4/0", loc="bottom", fontsize=8)
	259	bus = d.add(elm.RBox(w=1.1, h=3.4).label("DC\nBUSBAR\n250A", fontsize=9))
	260	busx = bus.center[0]
	261
	262	# two packs hanging off the busbar, each: Class-T + disconnect + battery
	263	for k in range(npack):
	264	yy = 1.0 - k * 2.2
	265	d += elm.Line().right().length(1.0).at((busx + 0.55, yy))
	266	d += elm.Fuse().right().label(f"{s04['per_pack_classT_fuse_A']}A\nClass-T", loc="top", fontsize=8)
	267	d += elm.SwitchDpst().right().label("disc", loc="bottom", fontsize=8)
	268	d += elm.Line().right().length(0.4)
	269	d += elm.Battery().right().label(
	270	f"Docan S3 #{k+1}\n51.2V·{ukwh}kWh\n{pk['final_gauge_AWG']}Cu·{pk['vdrop_pct']}%",
	271	loc="top", fontsize=8)
	272
	273	# negative return (busbar bottom -> inverter BATN)
	274	d += elm.Line().down().length(0.6).at((busx, -1.7))
	275	d += elm.Line().left().tox(inv.BATN[0]).label("− busbar return", loc="bottom", fontsize=8)
	276	d += elm.Line().up().toy(inv.BATN[1])
	277	# BMS comms (dashed): packs master/slave -> 18kPV CAN
	278	c = d.add(elm.Line(ls="--").down().length(1.4).at(inv.COM))
	279	d += elm.Line(ls="--").right().length(5.0).at(c.end).label(
	280	"JK-BMS master/slave → CAN → 18kPV (single link; confirm profile)", loc="bottom", fontsize=8)
	281
	282	cx, cy = inv.center
	283	title(d, f"FINAL-STATE BATTERY WIRING — 18kPV ↔ {npack}× Docan S3 bank", (cx + 2.8, cy + 2.9))
	284	d += elm.Label().label(
	285	f"Bank discharge @12kW = {s04['bank_discharge_A_12kW']:.0f}A (inverter cap 250A) → "
	286	f"{s04['per_pack_discharge_A']:.0f}A/pack · binding {s04['per_pack_binding']['name']} "
	287	f"{s04['per_pack_binding']['A']:.0f}A ({s04['per_pack_binding']['headroom_A']:.0f}A headroom) · "
	288	f"{s04['per_pack_discharge_C']}C · {s04['bank_usable_kwh_80dod']}kWh usable",
	289	fontsize=8).at((cx + 2.2, cy - 4.4))
	290	save(d, "battery-wiring", ART_P2)
	291
	292
	293	ART_PA = ART / "phase2" # Path A = SELECTED build (primary deliverable)
	294	CAP_PA = "PRSM OFF-GRID PV — SELECTED BUILD · PATH A (2× EG4 6000XP) · NEK Vermont · NEC 2023 · ratings trace to scripts 01/11"
	295
	296
	297	def sld_pathA(cfg, pa):
	298	"""Path-A single-line (clean single-spine layout; the explicit two-box detail is in the
	299	Path-A dc-strings + battery-wiring diagrams). 28-panel array → 2× 6000XP (parallel) → bank."""
	300	pv = pa["pv_string"]; acu = pa["ac_per_unit"]; acc = pa["ac_combined"]
	301	pk = pa["battery_per_pack"]; iv = pa["battery_per_inverter"]; m = pa["meta"]
	302	npack, n_classT = 2, pa["limits"]["classT_count"]
	303	bank_dod = pa["limits"]["bank_usable_kwh_80dod"]
	304	d = schemdraw.Drawing()
	305	d.config(fontsize=10, unit=2.7)
	306
	307	d += elm.Solar().right().label(
	308	f"PV ARRAY\n28×575W · {m['strings']}×7S\n{m['array_dc_W']}W DC\ncoldVoc {m['string_cold_voc_V']}V (≤480)",
	309	loc="bottom")
	310	d += elm.Line().right().length(2.6).label(
	311	f"{pv['final_gauge_AWG']}AWG×{pv['length_ft']}ft\n{pv['vdrop_pct']}% · 4 homeruns", loc="top")
	312	d += elm.SwitchDpst().right().label("DC\ndisc", loc="bottom")
	313	d += elm.Line().right().length(1.2)
	314	inv = d.add(elm.Ic(pins=[
	315	elm.IcPin(name="PV", side="left"), elm.IcPin(name="ACIN", side="top"),
	316	elm.IcPin(name="AC", side="right"),
	317	elm.IcPin(name="BATP", side="bottom", slot="1/4"), elm.IcPin(name="GND", side="bottom", slot="4/4"),
	318	], w=6.8, h=6.4).anchor("PV"))
	319	icx, icy = inv.center
	320	d += elm.Label().label("2× EG4 6000XP (parallel) · 12kW\n4 MPPT · 16kW PV · RSD·AFCI·GFDI ×2",
	321	fontsize=9).at((icx, icy + 1.55))
	322
	323	# generator AC-IN
	324	d += elm.Line().up().length(1.4).at(inv.ACIN)
	325	d += elm.SwitchDpst().up().label("gen AC-IN", loc="right", fontsize=9)
	326	d += elm.Line().up().length(0.6)
	327	d += elm.RBox(w=2.8, h=1.3).label("GENERATOR\n200A bypass · 90A gen", fontsize=8)
	328
	329	# AC: 2× 35A unit outputs combine to 70A → main panel
	330	d += elm.Line().right().length(1.8).at(inv.AC)
	331	d += elm.SwitchDpst().right().label(f"{acc['ocpd_A']}A\n2-pole", loc="top")
	332	d += elm.Line().right().length(1.3)
	333	d += elm.RBox(w=3.0, h=2.3).label(
	334	f"MAIN PANEL\nsubfed (main off)\n{acc['final_gauge_AWG']}AWG (2×{acu['ocpd_A']}A→{acc['ocpd_A']}A)", fontsize=9)
	335
	336	# battery branch → busbar → bank
	337	d += elm.Line().down().length(0.9).at(inv.BATP)
	338	d += elm.SwitchDpst().down().label("bank disc 250A", loc="right", fontsize=8)
	339	d += elm.Line().down().length(1.5).label(
	340	f"{iv['final_gauge_AWG']}Cu/inverter · {pa['bank']['i_inv_A']:.0f}A ea\n(2 inverters tap the bus)",
	341	loc="left", fontsize=8)
	342	d += elm.RBox(w=3.6, h=1.0).label("DC BUSBAR (250A)", fontsize=9)
	343	d += elm.Line().down().length(0.8)
	344	d += elm.Fuse().down().label(f"{n_classT}× {pa['limits']['classT_fuse_A']}A Class-T\n(2 packs + 2 inverters)", loc="right", fontsize=8)
	345	d += elm.Line().down().length(0.8)
	346	d += elm.Battery().down().label(
	347	f"{npack}× Docan S3 · 51.2V\n{bank_dod}kWh usable (80% DoD)\n{pk['final_gauge_AWG']}Cu/pack · "
	348	f"{pk['vdrop_pct']}% · JK-BMS×2 → CAN", loc="left", fontsize=8)
	349
	350	d += elm.Line().down().length(1.2).at(inv.GND)
	351	d += elm.Ground().label("GEC 6AWG\n690.47", loc="right", fontsize=8)
	352
	353	cx, cy = inv.center
	354	title(d, "PATH-A SINGLE-LINE — 2× EG4 6000XP (parallel)", (cx, cy + 7.4))
	355	d += elm.Label().label(CAP_PA, fontsize=8).at((cx, cy + 6.7))
	356	save(d, "sld", ART_PA)
	357
	358
	359	def dc_strings_pathA(cfg, pa):
	360	"""Path-A DC strings: 4× 7S, two strings per 6000XP (2 MPPTs each)."""
	361	pv = pa["pv_string"]; m = pa["meta"]
	362	vmp = round(7 * require(cfg, "panel.vmp_v"))
	363	cold = m["string_cold_voc_V"]
	364	d = schemdraw.Drawing()
	365	d.config(fontsize=10, unit=1.3)
	366	y = 0.0
	367	for i in range(4):
	368	unit = 1 if i < 2 else 2
	369	mppt = (i % 2) + 1
	370	d += elm.Label().label(f"String {i+1}\n7S (+)", fontsize=9).at((-1.7, y))
	371	d += elm.Solar().right().at((0, y)).label("7× Waaree 575W", loc="top", fontsize=8)
	372	d += elm.Line().right().length(1.0).label(f"{pv['final_gauge_AWG']}AWG", loc="top", fontsize=8)
	373	d += elm.Line().right().length(0.3).label(f"Vmp≈{vmp}V\ncoldVoc {cold}V", loc="bottom", fontsize=8)
	374	d += elm.RBox(w=2.2, h=1.0).label(f"6000XP #{unit}\nMPPT{mppt}", fontsize=8)
	375	y -= 1.8
	376	title(d, "PATH-A DC STRINGS — 4× 7S, two strings per 6000XP", (2.8, 1.6))
	377	d += elm.Label().label(
	378	f"#1: MPPT1+MPPT2 (7S+7S) · #2: MPPT1+MPPT2 (7S+7S) · 28 modules · {m['array_dc_W']}W DC\n"
	379	f"7S cold Voc {cold}V ≤ 480V design / 500V abs · 1 string/MPPT → NO source fuse · 3 panels held as spares",
	380	fontsize=8).at((2.8, y - 0.4))
	381	save(d, "dc-strings", ART_PA)
	382
	383
	384	def battery_wiring_pathA(cfg, pa):
	385	"""Path-A battery: busbar fed by 2 packs, feeding 2× 6000XP inputs; per-pack + per-inverter Class-T."""
	386	pk = pa["battery_per_pack"]; iv = pa["battery_per_inverter"]; L = pa["limits"]; bk = pa["bank"]
	387	npack = 2; fuse = L["classT_fuse_A"]; ukwh = require(cfg, "battery.usable_kwh")
	388	d = schemdraw.Drawing()
	389	d.config(fontsize=9, unit=1.1)
	390	# central vertical busbar
	391	d += elm.Line().up().length(2.6).at((0, 0))
	392	d += elm.Line().down().length(2.6).at((0, 0))
	393	d += elm.Label().label("DC BUSBAR\n250A", fontsize=9).at((0, 0.0))
	394
	395	# left: 2 packs in
	396	for k in range(npack):
	397	yy = 1.6 - k * 3.2
	398	d += elm.Line().left().length(1.0).at((0, yy))
	399	d += elm.Fuse().left().label(f"{fuse}A\nClass-T", loc="top", fontsize=7)
	400	d += elm.SwitchDpst().left().label("disc", loc="bottom", fontsize=7)
	401	d += elm.Battery().left().label(f"Docan S3 #{k+1}\n51.2V·{ukwh}kWh\n{pk['final_gauge_AWG']}Cu", loc="top", fontsize=7)
	402	# right: 2 inverters out
	403	for k in range(npack):
	404	yy = 1.6 - k * 3.2
	405	d += elm.Line().right().length(1.0).at((0, yy))
	406	d += elm.Fuse().right().label(f"{fuse}A\nClass-T", loc="top", fontsize=7)
	407	d += elm.SwitchDpst().right().label("disc", loc="bottom", fontsize=7)
	408	d += elm.RBox(w=2.0, h=1.2).label(f"6000XP #{k+1}\nBAT max140A\n{iv['final_gauge_AWG']}Cu", fontsize=7)
	409
	410	title(d, "PATH-A BATTERY WIRING — busbar: 2 packs → 2× 6000XP", (0, 5.0))
	411	d += elm.Label().label(
	412	f"Bank {bk['i_bank_A']:.0f}A @12kW → {bk['i_pack_A']:.0f}A/pack (17% under 150A BMS) + "
	413	f"{bk['i_inv_A']:.0f}A/inverter (14A under 140A) · {L['c_dis']}C · {npack+npack}× {fuse}A Class-T · "
	414	f"2× JK-BMS → CAN (one per inverter)", fontsize=7).at((0, -5.2))
	415	save(d, "battery-wiring", ART_PA)
	416
	417
	418	def main():
	419	ap = argparse.ArgumentParser()
	420	ap.add_argument("--phase2", action="store_true",
	421	help="render the final-state diagrams to artifacts/phase2/")
	422	ap.add_argument("--pathA", action="store_true",
	423	help="render the SELECTED Path-A (2× 6000XP) diagrams to artifacts/phase2/")
	424	args = ap.parse_args()
	425	if args.pathA:
	426	cfg = load_site()
	427	banner("06 SCHEMATICS [SELECTED PATH A — 2× 6000XP -> artifacts/phase2/]")
	428	pa = load_result("11_pathA")
	429	ok = []
	430	for name, fn in [("sld", lambda: sld_pathA(cfg, pa)),
	431	("dc-strings", lambda: dc_strings_pathA(cfg, pa)),
	432	("battery-wiring", lambda: battery_wiring_pathA(cfg, pa))]:
	433	try:
	434	fn(); ok.append(name)
	435	except Exception as e: # noqa
	436	import traceback
	437	print(f" [FAIL] {name}: {type(e).__name__}: {e}")
	438	traceback.print_exc()
	439	print(f"\n rendered OK: {ok}")
	440	return
	441	cfg = load_site(phase2=args.phase2)
	442	if is_phase2(cfg):
	443	banner("06 SCHEMATICS [PHASE 2 — final state -> artifacts/phase2/]")
	444	s01 = load_result("01_string_phase2")
	445	s03 = load_result("03_conductors_phase2")
	446	s04 = load_result("04_battery_phase2")
	447	ok = []
	448	for name, fn in [("sld", lambda: sld_p2(cfg, s01, s03, s04)),
	449	("dc-strings", lambda: dc_strings_p2(cfg, s01, s03)),
	450	("battery-wiring", lambda: battery_wiring_p2(cfg, s03, s04))]:
	451	try:
	452	fn(); ok.append(name)
	453	except Exception as e: # noqa
	454	import traceback
	455	print(f" [FAIL] {name}: {type(e).__name__}: {e}")
	456	traceback.print_exc()
	457	print(f"\n rendered OK: {ok}")
	458	return
	459
	460	cfg = load_site()
	461	banner("06 SCHEMATICS (schemdraw -> PNG + SVG)")
	462	s01 = load_result("01_string")
	463	s03 = load_result("03_conductors")
	464	s04 = load_result("04_battery")
	465	ok = []
	466	for name, fn in [("sld", lambda: sld(cfg, s01, s03, s04)),
	467	("dc-strings", lambda: dc_strings(cfg, s01, s03)),
	468	("battery-wiring", lambda: battery_wiring(cfg, s03, s04))]:
	469	try:
	470	fn()
	471	ok.append(name)
	472	except Exception as e: # noqa
	473	import traceback
	474	print(f" [FAIL] {name}: {type(e).__name__}: {e}")
	475	traceback.print_exc()
	476	print(f"\n rendered OK: {ok}")
	477
	478
	479	if __name__ == "__main__":
	480	main()

scripts/07_load_capacity.py +76 -0

…	…	@@ -0,0 +1,76 @@
	1	"""07 — Supportable household-load envelope (energy + power + autonomy).
	2
	3	NOT a load study — the household's actual load profile is still an open item (HANDOFF).
	4	This BOUNDS what daily kWh and instantaneous kW THIS configuration can support, from the
	5	computed winter-binding production (02) and the battery/inverter limits (04). Off-grid the
	6	binding constraint is winter production; the battery sets short-term autonomy; the Phase-1
	7	generator backfills multi-day deficits.
	8
	9	Run (after 02, 04): ~/.venvs/prsm-electrical/bin/python scripts/07_load_capacity.py
	10	"""
	11	from common import load_site, require, banner, result, dump_result, load_result
	12
	13	# Fraction of delivered AC production usable as household load. PVWatts already applied a
	14	# 14% system loss to AC, so this band is mainly LiFePO4 round-trip (~0.95) on the
	15	# time-shifted energy plus a practical reserve. A band, not a point estimate.
	16	USE_LO, USE_HI = 0.85, 0.95
	17	DAYS = [31, 28, 31, 30, 31, 30, 31, 31, 30, 31, 30, 31]
	18
	19
	20	def main():
	21	cfg = load_site()
	22	banner("07 SUPPORTABLE HOUSEHOLD LOAD (energy + power + autonomy)")
	23	p = load_result("02_production")
	24
	25	m = p["ac_monthly_kwh"]
	26	dec = p["dec_kwh_day"]
	27	jun = p["jun_kwh_day"]
	28	winter = round((m[0] + m[11]) / (DAYS[0] + DAYS[11]), 1) # Dec+Jan per day
	29	shoulder = round(sum(m[i] / DAYS[i] for i in (2, 3, 8, 9)) / 4, 1) # Mar/Apr/Sep/Oct
	30	annual = round(p["ac_annual_kwh"] / 365.0, 1)
	31
	32	inv_w = require(cfg, "inverter.ac_continuous_w")
	33	surge_w = require(cfg, "inverter.ac_surge_w")
	34	leg_a = require(cfg, "inverter.ac_cont_a_per_leg")
	35	usable = require(cfg, "battery.usable_kwh")
	36	dod = require(cfg, "battery.dod_design")
	37	usable_dod = round(usable * dod, 1)
	38
	39	seasons = [("Deep winter (Dec)", dec), ("Winter avg (Dec-Jan)", winter),
	40	("Shoulder (Mar/Apr/Sep/Oct)", shoulder), ("Summer (Jun)", jun),
	41	("Annual avg", annual)]
	42
	43	print("\n ENERGY — supportable daily load, solar-only (production x 0.85-0.95):")
	44	print(f" {'season':<28}{'AC produced':>13}{'usable load':>18}")
	45	rows = []
	46	for name, prod in seasons:
	47	lo, hi = USE_LO * prod, USE_HI * prod
	48	print(f" {name:<28}{prod:>9.1f} kWh{f'{lo:.0f}-{hi:.0f} kWh/day':>18}")
	49	rows.append({"season": name, "ac_kwh_day": prod,
	50	"supportable_kwh_day": [round(lo), round(hi)]})
	51
	52	print("\n POWER — instantaneous envelope (inverter limits, from 02/04):")
	53	result(" continuous", inv_w, "W", "max sum of simultaneous loads")
	54	result(" surge (3.5 s)", surge_w, "W", "motor / compressor starts")
	55	result(" per 120 V leg", leg_a, "A", "~3 kW per leg of split-phase")
	56
	57	print(f"\n AUTONOMY — one battery, usable {usable_dod} kWh @ {dod*100:.0f}% DoD:")
	58	print(f" {'daily load':>12}{'days w/o sun':>16}")
	59	auton = {}
	60	for daily in (5, 8, 10, 13, 20):
	61	d = round(usable_dod / daily, 2)
	62	print(f" {daily:>8} kWh{d:>13} days")
	63	auton[str(daily)] = d
	64
	65	dump_result("07_load_capacity", {
	66	"production_kwh_day": {n: v for n, v in seasons},
	67	"usage_band": [USE_LO, USE_HI],
	68	"supportable_daily_load_kwh": rows,
	69	"inverter_continuous_W": inv_w, "inverter_surge_W": surge_w, "per_leg_A": leg_a,
	70	"battery_usable_kwh_80dod": usable_dod, "days_autonomy": auton,
	71	"note": "capacity envelope, not a load study; generator backfills winter deficit",
	72	})
	73
	74
	75	if __name__ == "__main__":
	76	main()

scripts/08_load_actual.py +117 -0

…	…	@@ -0,0 +1,117 @@
	1	"""08 — Actual household load (Hardwick Electric) vs system capacity.
	2
	3	Real billed kWh from the owner's Hardwick Electric Dept account, finally closing the
	4	"load baseline" open item (Key Decisions §46, Swarm §1). Compares actual usage against
	5	the supportable-load envelope (07) and production (02).
	6
	7	The raw billing series is saved in data/hardwick_usage.csv (provenance in its header)
	8	and loaded via common.load_usage() so any calc can reuse it — this script no longer
	9	embeds the numbers.
	10
	11	Run: ~/.venvs/prsm-electrical/bin/python scripts/08_load_actual.py
	12	"""
	13	from common import banner, result, dump_result, load_result, load_usage
	14
	15	DIM = {"01": 31, "02": 28, "03": 31, "04": 30, "05": 31, "06": 30,
	16	"07": 31, "08": 31, "09": 30, "10": 31, "11": 30, "12": 31}
	17	SEASON = {"12": "winter", "01": "winter", "02": "winter",
	18	"06": "summer", "07": "summer", "08": "summer",
	19	"03": "shoulder", "04": "shoulder", "05": "shoulder",
	20	"09": "shoulder", "10": "shoulder", "11": "shoulder"}
	21
	22
	23	def mm(entry):
	24	return entry["bill_date"][:2]
	25
	26
	27	def daily_avg(entries):
	28	kwh = sum(e["net_kwh"] for e in entries)
	29	days = sum(DIM[mm(e)] for e in entries)
	30	return kwh, days, kwh / days
	31
	32
	33	def main():
	34	banner("08 ACTUAL LOAD (Hardwick Electric) vs CAPACITY")
	35	p07 = load_result("07_load_capacity")
	36	p02 = load_result("02_production")
	37	ledger = load_usage() # data/hardwick_usage.csv, newest first
	38
	39	last12 = ledger[:12]
	40	kwh12, days12, dpd12 = daily_avg(last12)
	41	result("source", "data/hardwick_usage.csv", "", f"{len(ledger)} months on file")
	42	result("last 12 mo total", round(kwh12), "kWh/yr", "Jun 2025 – May 2026")
	43	result("monthly average", round(kwh12 / 12), "kWh/mo")
	44	result("DAILY average", round(dpd12, 1), "kWh/day")
	45	months = [e["net_kwh"] for e in last12]
	46	result("min / max month", f"{min(months)} / {max(months)}", "kWh",
	47	"Jan 744 / Aug 1677 — SUMMER-peaking")
	48
	49	print("\n MONTHLY DETAIL (last 12 mo) — kWh · net cost · avg $/kWh:")
	50	print(f" {'month':>9}{'kWh':>7}{'net $':>10}{'$/kWh':>9}")
	51	for e in last12:
	52	print(f" {e['bill_date']:>9}{e['net_kwh']:>7}{e['bill_amount']:>10.2f}"
	53	f"{e['avg_cost_per_kwh']:>9.3f}")
	54
	55	seas = {}
	56	for s in ("winter", "shoulder", "summer"):
	57	grp = [e for e in last12 if SEASON[mm(e)] == s]
	58	_, _, dpd = daily_avg(grp)
	59	seas[s] = round(dpd, 1)
	60	aug = next(e["net_kwh"] for e in last12 if mm(e) == "08") / 31
	61	print()
	62	result("winter daily avg (D/J/F)", seas["winter"], "kWh/day")
	63	result("shoulder daily avg", seas["shoulder"], "kWh/day")
	64	result("summer daily avg (J/J/A)", seas["summer"], "kWh/day")
	65	result(" August peak", round(aug, 1), "kWh/day", "the binding month for THIS load")
	66
	67	sup = {r["season"]: r["supportable_kwh_day"] for r in p07["supportable_daily_load_kwh"]}
	68	prod = p07["production_kwh_day"]
	69	pairs = [("winter", seas["winter"], sup["Winter avg (Dec-Jan)"], prod["Winter avg (Dec-Jan)"]),
	70	("shoulder", seas["shoulder"], sup["Shoulder (Mar/Apr/Sep/Oct)"], prod["Shoulder (Mar/Apr/Sep/Oct)"]),
	71	("summer", seas["summer"], sup["Summer (Jun)"], prod["Summer (Jun)"]),
	72	("August", aug, sup["Summer (Jun)"], prod["Summer (Jun)"])]
	73
	74	print("\n ACTUAL vs SUPPORTABLE (solar-only):")
	75	print(f" {'season':<10}{'actual':>9}{'supportable':>14}{'solar prod':>12}{'solar covers':>14}")
	76	cmp = {}
	77	for name, act, s, pr in pairs:
	78	cover = 100 * pr / act
	79	print(f" {name:<10}{act:>7.1f} {f'{s[0]}-{s[1]}':>12} {pr:>9.1f} {cover:>10.0f}% ")
	80	cmp[name] = {"actual_kwh_day": round(act, 1), "supportable": s,
	81	"solar_prod_kwh_day": pr, "solar_covers_pct": round(cover)}
	82
	83	ann_prod = p02["ac_annual_kwh"]
	84	bal = 100 * ann_prod / kwh12
	85	print()
	86	result("annual production (02)", ann_prod, "kWh/yr")
	87	result("annual consumption", round(kwh12), "kWh/yr")
	88	result("array = % of annual load", round(bal), "%", "8 kW array UNDERSIZED vs full load")
	89	annual_cost = sum(e["bill_amount"] for e in last12)
	90	wavg = annual_cost / kwh12
	91	costs = [e["bill_amount"] for e in last12]
	92	result("annual electric cost", round(annual_cost, 2), "$/yr", "sum of last 12 bills")
	93	result("weighted avg cost", round(wavg, 3), "$/kWh", "annual cost / annual kWh")
	94	result("min / max monthly bill", f"{min(costs):.2f} / {max(costs):.2f}", "$")
	95
	96	verdict = ("Phase-1 (~8 kW / 16 kWh) offsets ~half (Aug) to ~90% (shoulder) of this load "
	97	"by season; full off-grid coverage needs load reduction (propane/shedding) + the "
	98	"Phase-2 PV expansion + 2nd battery. Confirms Swarm 'Phase 2 = more PV'.")
	99	print("\n VERDICT:", verdict)
	100
	101	dump_result("08_load_actual", {
	102	"source": "data/hardwick_usage.csv",
	103	"last12_kwh_yr": round(kwh12), "monthly_avg_kwh": round(kwh12 / 12),
	104	"daily_avg_kwh": round(dpd12, 1),
	105	"min_month_kwh": min(months), "max_month_kwh": max(months),
	106	"seasonal_daily_kwh": seas, "august_peak_kwh_day": round(aug, 1),
	107	"vs_supportable": cmp,
	108	"annual_production_kwh": ann_prod, "array_pct_of_load": round(bal),
	109	"annual_cost_usd": round(annual_cost, 2),
	110	"weighted_avg_cost_per_kwh": round(wavg, 3),
	111	"min_monthly_bill_usd": min(costs), "max_monthly_bill_usd": max(costs),
	112	"verdict": verdict,
	113	})
	114
	115
	116	if __name__ == "__main__":
	117	main()

scripts/09_phase2.py +140 -0

…	…	@@ -0,0 +1,140 @@
	1	"""09 — Phase-2 sizing + cost: wire the REMAINING pallet panels to meet the load.
	2
	3	Phase-1 wired 14 of the 31-panel Waaree pallet (8.05 kW) and that already MAXES the
	4	single EG4 6000XP PV input (8 kW usable/unit). To use the remaining 17 panels (9.78 kW
	5	-> 17.8 kW full pallet) you must add INVERTER capacity; the panels themselves are already
	6	paid for (sunk in the pallet) = $0 additional.
	7
	8	Computes (grounded): full-pallet production (PVWatts), coverage vs the real Hardwick load
	9	(08), and battery autonomy. Cost figures are ESTIMATES (sourced: Swarm §10 / Key Decisions),
	10	not computed — clearly labeled.
	11
	12	Run: ~/.venvs/prsm-electrical/bin/python scripts/09_phase2.py (uses NREL_API_KEY or DEMO_KEY)
	13	"""
	14	import os
	15	import requests
	16	from common import load_site, require, banner, result, dump_result, load_result
	17
	18	HOSTS = ["https://developer.nrel.gov", "https://developer.nlr.gov"]
	19	DAYS = [31, 28, 31, 30, 31, 30, 31, 31, 30, 31, 30, 31]
	20
	21	# --- COST ESTIMATES (USD) — NOT computed; sourced as noted. Ranges (lo, hi). ---
	22	INV_6000XP = 1549 # Key Decisions (retail)
	23	INV_6000XP_RESALE = (800, 1000) # Swarm §10 "strong secondary market"
	24	INV_18KPV = 4500 # Swarm §10
	25	PARALLEL_KIT = 150 # parallel comms/cabling kit (est)
	26	DOCAN = (1758, 2000) # Key Decisions base SKU (heating is propane/separate)
	27	BOS_PH2 = (800, 1500) # PV wire for 17 panels, DC disc, battery interconnects, AC upsize, lugs/MC4 (est)
	28
	29
	30	def pvwatts(kw, dc_ac, cfg):
	31	key = os.environ.get("NREL_API_KEY", "DEMO_KEY")
	32	params = {"api_key": key, "system_capacity": kw, "module_type": 0, "array_type": 0,
	33	"tilt": require(cfg, "array.tilt_deg"), "azimuth": require(cfg, "array.azimuth_deg"),
	34	"losses": 14, "lat": require(cfg, "site.latitude"),
	35	"lon": require(cfg, "site.longitude"), "dc_ac_ratio": round(dc_ac, 3)}
	36	for host in HOSTS:
	37	try:
	38	r = requests.get(host + "/api/pvwatts/v8.json", params=params, timeout=30)
	39	if r.status_code == 200 and "outputs" in r.json():
	40	return r.json()["outputs"], host
	41	except Exception: # noqa
	42	pass
	43	return None, None
	44
	45
	46	def rng(lo, hi):
	47	return f"${lo:,.0f}-{hi:,.0f}"
	48
	49
	50	def main():
	51	cfg = load_site()
	52	banner("09 PHASE-2 — use remaining pallet to meet the load (sizing + cost)")
	53	load = load_result("08_load_actual")
	54	pmp = require(cfg, "panel.pmp_w")
	55
	56	n_total, n_ph1 = 31, int(require(cfg, "array.module_count"))
	57	n_remaining = n_total - n_ph1
	58	kw_ph1 = round(n_ph1 * pmp / 1000, 2)
	59	kw_full = round(n_total * pmp / 1000, 2)
	60	result("pallet / Phase-1 / remaining", f"{n_total} / {n_ph1} / {n_remaining}", "panels")
	61	result("array kW: Phase-1 -> full", f"{kw_ph1} -> {kw_full}", "kW DC")
	62	result("CONSTRAINT", "1× 6000XP PV input = 8 kW usable", "",
	63	"Phase-1 8.05 kW already maxes it -> Phase-2 needs more inverter")
	64
	65	# --- production at full pallet (12 kW AC from expanded inverter) ---
	66	out, host = pvwatts(kw_full, kw_full / 12.0, cfg)
	67	if out is None:
	68	raise SystemExit("PVWatts unavailable; set NREL_API_KEY and retry.")
	69	m = out["ac_monthly"]
	70	ann = out["ac_annual"]
	71	dec = m[11] / DAYS[11]
	72	winter = (m[0] + m[11]) / (DAYS[0] + DAYS[11])
	73	summer = sum(m[i] / DAYS[i] for i in (5, 6, 7)) / 3
	74	print(f"\n FULL-PALLET PRODUCTION ({kw_full} kW, via {host.split('//')[1]}):")
	75	result(" annual", round(ann), "kWh/yr", f"vs load {load['last12_kwh_yr']} kWh/yr")
	76	result(" array = % of annual load", round(100 * ann / load["last12_kwh_yr"]), "%",
	77	"now EXCEEDS load (was 79% at Phase-1)")
	78	result(" Dec / winter avg", f"{dec:.1f} / {winter:.1f}", "kWh/day",
	79	f"vs winter load {load['seasonal_daily_kwh']['winter']}")
	80	result(" summer avg", round(summer, 1), "kWh/day",
	81	f"vs summer load {load['seasonal_daily_kwh']['summer']} / Aug {load['august_peak_kwh_day']}")
	82
	83	# coverage vs load by season (solar-only, usage band 0.85)
	84	print("\n COVERAGE vs load (full pallet, x0.85 usable):")
	85	seas = load["seasonal_daily_kwh"]
	86	for name, prod_d, ld in [("winter", winter, seas["winter"]),
	87	("summer", summer, seas["summer"]),
	88	("Aug peak", summer, load["august_peak_kwh_day"])]:
	89	cov = 100 * (0.85 * prod_d) / ld
	90	result(f" {name}", f"{0.85*prod_d:.0f} usable vs {ld} load", "kWh/day",
	91	f"{cov:.0f}% ({'MET' if cov >= 100 else 'gen/short'})")
	92
	93	# --- battery autonomy at the load ---
	94	usable_pack = round(require(cfg, "battery.usable_kwh") * require(cfg, "battery.dod_design"), 2)
	95	avg = load["daily_avg_kwh"]; peak = load["august_peak_kwh_day"]
	96	print(f"\n BATTERY AUTONOMY ({usable_pack} kWh usable/pack @ 80% DoD):")
	97	print(f" {'packs':>6}{'usable':>9}{'days@avg':>11}{'days@peak':>11}")
	98	for n in (1, 2, 3):
	99	u = usable_pack * n
	100	print(f" {n:>6}{u:>7.1f}kWh{u/avg:>10.2f}{u/peak:>11.2f}")
	101	result("Swarm §6 battery target", "24-30 kWh usable", "", "= 2 packs (25.7 usable); 3 for ~1 day @ avg")
	102
	103	# --- COST (estimates) ---
	104	print("\n PHASE-2 ADDED COST (estimates; energy/autonomy above are computed):")
	105	result(" remaining 17 panels", "$0", "", "already paid (sunk in pallet)")
	106	par_inv = INV_6000XP + PARALLEL_KIT
	107	swap_inv = (INV_18KPV - INV_6000XP_RESALE[1], INV_18KPV - INV_6000XP_RESALE[0])
	108	result(" inverter A: parallel 2nd 6000XP", f"${par_inv:,}", "", "12 kW AC / 16 kW PV (Key Dec §76)")
	109	result(" inverter B: 18kPV swap (−resale)", rng(*swap_inv), "",
	110	"18 kW PV / 12 kW AC; Swarm §10 recommends for >10 kW")
	111	result(" battery: +1 pack (→2 total)", rng(*DOCAN), "", "25.7 kWh usable (Swarm §6 min)")
	112	result(" battery: +2 packs (→3 total)", rng(2*DOCAN[0], 2*DOCAN[1]), "", "38.6 kWh usable, ~1 day @ avg")
	113	result(" BoS (PV wire/disc/cables/AC upsize)", rng(*BOS_PH2))
	114
	115	# bundles
	116	lean_lo = par_inv + DOCAN[0] + BOS_PH2[0]
	117	lean_hi = par_inv + DOCAN[1] + BOS_PH2[1]
	118	rec_lo = swap_inv[0] + 2*DOCAN[0] + BOS_PH2[0]
	119	rec_hi = swap_inv[1] + 2*DOCAN[1] + BOS_PH2[1]
	120	print()
	121	result(" BUNDLE — Lean (parallel 6000XP + 1 pack)", rng(lean_lo, lean_hi), "",
	122	"2 packs, 12 kW AC; generator covers deep autonomy")
	123	result(" BUNDLE — Recommended (18kPV + 2 packs)", rng(rec_lo, rec_hi), "",
	124	"3 packs, single-inverter, Swarm §10 path")
	125
	126	dump_result("09_phase2", {
	127	"remaining_panels": n_remaining, "kw_full_pallet": kw_full,
	128	"full_pallet_annual_kwh": round(ann), "array_pct_of_load": round(100 * ann / load["last12_kwh_yr"]),
	129	"dec_kwh_day": round(dec, 1), "winter_kwh_day": round(winter, 1), "summer_kwh_day": round(summer, 1),
	130	"panels_added_cost": 0,
	131	"inverter_parallel_6000xp": par_inv, "inverter_18kpv_swap_net": list(swap_inv),
	132	"battery_plus1_pack": list(DOCAN), "battery_plus2_packs": [2*DOCAN[0], 2*DOCAN[1]],
	133	"bos": list(BOS_PH2),
	134	"bundle_lean_usd": [lean_lo, lean_hi], "bundle_recommended_usd": [rec_lo, rec_hi],
	135	"note": "panels $0 (owned); cost figures estimates (Swarm §10/Key Decisions); energy computed",
	136	})
	137
	138
	139	if __name__ == "__main__":
	140	main()

scripts/10_compare_inverter_paths.py +144 -0

…	…	@@ -0,0 +1,144 @@
	1	"""10 — Inverter-path comparison (script-computed numbers for the design tradeoff).
	2
	3	Path A: 2x EG4 6000XP in parallel, 28 panels = 4x7S (16.1 kW DC), 3 panels held as spares.
	4	Path B: 1x EG4 18kPV, 31 panels = 8+8+8+7S (17.8 kW DC). [the chosen design]
	5
	6	Both target 12 kW AC. Computes — for each path — production (PVWatts v8, same site/tilt/az),
	7	coverage vs the real Hardwick load, PV-usable headroom, AC, and battery discharge limit/headroom.
	8	String cold-Voc is pulled from the already-validated results (01 = 7S/430V, 01_phase2 = 8S/491.5V).
	9	Cost is a LABELED estimate (Swarm §10), not computed.
	10
	11	Run: ~/.venvs/prsm-electrical/bin/python scripts/10_compare_inverter_paths.py
	12	"""
	13	import os
	14	import requests
	15	from common import load_site, require, banner, result, dump_result, load_result
	16
	17	HOSTS = ["https://developer.nrel.gov", "https://developer.nlr.gov"]
	18	DAYS = [31, 28, 31, 30, 31, 30, 31, 31, 30, 31, 30, 31]
	19
	20
	21	def pvwatts(kw, dc_ac, cfg):
	22	key = os.environ.get("NREL_API_KEY", "DEMO_KEY")
	23	params = {"api_key": key, "system_capacity": kw, "module_type": 0, "array_type": 0,
	24	"tilt": require(cfg, "array.tilt_deg"), "azimuth": require(cfg, "array.azimuth_deg"),
	25	"losses": 14, "lat": require(cfg, "site.latitude"),
	26	"lon": require(cfg, "site.longitude"), "dc_ac_ratio": round(dc_ac, 3)}
	27	for host in HOSTS:
	28	try:
	29	r = requests.get(host + "/api/pvwatts/v8.json", params=params, timeout=30)
	30	if r.status_code == 200 and "outputs" in r.json():
	31	return r.json()["outputs"], host
	32	except Exception: # noqa
	33	pass
	34	return None, None
	35
	36
	37	def season(m):
	38	dec = m[11] / DAYS[11]
	39	winter = (m[0] + m[11]) / (DAYS[0] + DAYS[11])
	40	summer = sum(m[i] / DAYS[i] for i in (5, 6, 7)) / 3
	41	return dec, winter, summer
	42
	43
	44	def main():
	45	base = load_site() # base inverter: = EG4 6000XP
	46	p2 = load_site(phase2=True) # phase2.inverter = EG4 18kPV
	47	load = load_result("08_load_actual")
	48	pmp = require(base, "panel.pmp_w")
	49	vnom = require(base, "battery.nominal_v")
	50	npack = int(require(p2, "battery.pack_count")) # 2 either way
	51	ac_w = 12000.0 # both target 12 kW AC
	52	yr_load = load["last12_kwh_yr"]; seas_load = load["seasonal_daily_kwh"]
	53	aug = load["august_peak_kwh_day"]; avg = load["daily_avg_kwh"]
	54
	55	banner("10 INVERTER PATH COMPARISON (Path A 2x6000XP/28 vs Path B 18kPV/31)")
	56
	57	# ---- static specs from site.yaml (both inverters already confirmed) ----
	58	A = {"name": "A: 2x EG4 6000XP", "panels": 28, "strings": 4, "series": "4x7S",
	59	"kw": round(28 * pmp / 1000, 2),
	60	"pv_usable_w": 2 * require(base, "inverter.pv_max_power_w"),
	61	"ac_w": 2 * require(base, "inverter.ac_continuous_w"),
	62	"batt_lim_a": 2 * require(base, "inverter.batt_max_discharge_a"),
	63	"eff": require(base, "inverter.discharge_eff"),
	64	"string_voc": load_result("01_string")["string_cold_voc_V"],
	65	"voc_ceiling": require(base, "inverter.pv_design_voc_ceiling_v"),
	66	"mppts": 2 * require(base, "inverter.mppt_count"), "units": 2,
	67	"comms_links": 2, "spares": 3}
	68	B = {"name": "B: 1x EG4 18kPV", "panels": 31, "strings": 4, "series": "8+8+8+7S",
	69	"kw": round(31 * pmp / 1000, 2),
	70	"pv_usable_w": require(p2, "inverter.pv_max_power_w"),
	71	"ac_w": require(p2, "inverter.ac_continuous_w"),
	72	"batt_lim_a": require(p2, "inverter.batt_max_discharge_a"),
	73	"eff": require(p2, "inverter.discharge_eff"),
	74	"string_voc": load_result("01_string_phase2")["string_cold_voc_V"],
	75	"voc_ceiling": require(p2, "inverter.pv_design_voc_ceiling_v"),
	76	"mppts": require(p2, "inverter.mppt_count"), "units": 1,
	77	"comms_links": 1, "spares": 0}
	78
	79	for P in (A, B):
	80	out, host = pvwatts(P["kw"], P["kw"] / 12.0, base)
	81	if out is None:
	82	raise SystemExit("PVWatts unavailable; set NREL_API_KEY and retry.")
	83	m = out["ac_monthly"]
	84	P["annual"] = round(out["ac_annual"])
	85	P["dec"], P["winter"], P["summer"] = (round(x, 1) for x in season(m))
	86	P["pct_load"] = round(100 * P["annual"] / yr_load)
	87	# solar-only seasonal coverage (x0.85 usable), same convention as 08/09
	88	P["cov_winter"] = round(100 * 0.85 * P["winter"] / seas_load["winter"])
	89	P["cov_summer"] = round(100 * 0.85 * P["summer"] / seas_load["summer"])
	90	P["cov_aug"] = round(100 * 0.85 * P["summer"] / aug)
	91	P["host"] = host.split("//")[1]
	92	# PV-usable headroom (array DC vs inverter usable PV)
	93	P["pv_headroom_w"] = P["pv_usable_w"] - P["kw"] * 1000
	94	# battery discharge at 12 kW
	95	ib = ac_w / P["eff"] / vnom
	96	P["i_bank"] = round(ib, 1)
	97	P["i_pack"] = round(ib / npack, 1)
	98	P["batt_headroom_a"] = round(P["batt_lim_a"] - ib, 1)
	99
	100	# ---- print comparison ----
	101	rows = [
	102	("panels wired / spares", f"{A['panels']} / {A['spares']}", f"{B['panels']} / {B['spares']}"),
	103	("array DC", f"{A['kw']} kW", f"{B['kw']} kW"),
	104	("string config / cold Voc", f"{A['series']} / {A['string_voc']}V (≤{A['voc_ceiling']})",
	105	f"{B['series']} / {B['string_voc']}V (≤{B['voc_ceiling']})"),
	106	("MPPTs / units / comms links", f"{A['mppts']} / {A['units']} / {A['comms_links']}",
	107	f"{B['mppts']} / {B['units']} / {B['comms_links']}"),
	108	("PV usable / headroom", f"{A['pv_usable_w']}W / {A['pv_headroom_w']:+.0f}W",
	109	f"{B['pv_usable_w']}W / {B['pv_headroom_w']:+.0f}W"),
	110	("AC continuous", f"{A['ac_w']:.0f}W", f"{B['ac_w']:.0f}W"),
	111	("battery discharge limit", f"{A['batt_lim_a']:.0f}A (2x140)", f"{B['batt_lim_a']:.0f}A"),
	112	("12kW bank / per-pack draw", f"{A['i_bank']}/{A['i_pack']}A", f"{B['i_bank']}/{B['i_pack']}A"),
	113	("battery limit headroom", f"{A['batt_headroom_a']:+.0f}A", f"{B['batt_headroom_a']:+.0f}A"),
	114	("annual production", f"{A['annual']} kWh", f"{B['annual']} kWh"),
	115	(" = % of load", f"{A['pct_load']}%", f"{B['pct_load']}%"),
	116	("coverage winter/summer/Aug", f"{A['cov_winter']}/{A['cov_summer']}/{A['cov_aug']}%",
	117	f"{B['cov_winter']}/{B['cov_summer']}/{B['cov_aug']}%"),
	118	("Dec kWh/day", f"{A['dec']}", f"{B['dec']}"),
	119	]
	120	w = max(len(r[0]) for r in rows)
	121	print(f"\n {'metric':<{w}} {'PATH A (2x6000XP/28)':<26} {'PATH B (18kPV/31)':<22}")
	122	print(" " + "-" * (w + 50))
	123	for label, a, b in rows:
	124	print(f" {label:<{w}} {a:<26} {b:<22}")
	125
	126	dprod = B["annual"] - A["annual"]
	127	print(f"\n Production delta (B - A): +{dprod} kWh/yr ({round(100*dprod/A['annual'],1)}% more for B)")
	128	for P in (A, B):
	129	covs = [P["cov_winter"], P["cov_summer"], P["cov_aug"]]
	130	P["meets_all_seasons"] = all(c >= 100 for c in covs)
	131	short = [s for s, c in zip(("winter", "summer", "Aug"), covs) if c < 100]
	132	result(f"{P['name']} meets all seasons (solar x0.85)?",
	133	"YES" if P["meets_all_seasons"] else f"NO — short: {','.join(short)}",
	134	"", f"covers {P['cov_winter']}/{P['cov_summer']}/{P['cov_aug']}% W/S/Aug; "
	135	f"battery+generator backfill the rest off-grid")
	136	result("cost delta (ESTIMATE)", "B ≈ +$1,900 vs A", "", "Swarm §10: 18kPV net swap vs 2nd 6000XP (~$1,700)")
	137
	138	dump_result("10_compare", {"path_A": A, "path_B": B,
	139	"production_delta_kwh": dprod,
	140	"note": "production/loading computed (PVWatts + datasheet limits); cost is estimate"})
	141
	142
	143	if __name__ == "__main__":
	144	main()

scripts/11_pathA.py +197 -0

…	…	@@ -0,0 +1,197 @@
	1	"""11 — Path A variant design: 2x EG4 6000XP (parallel), 28 panels (4x7S), 2-pack bank.
	2
	3	The alternative to the chosen Path B (1x EG4 18kPV). Owner's other choices unchanged:
	4	2 packs, battery adjacent (~10 ft), 17 panels co-located on the 200 ft trench. Here 28 of the
	5	31 panels are wired (4x7S, 16.1 kW); the 3 remaining panels are held as field SPARES.
	6
	7	String safety is the already-validated Phase-1 7S result (430.1 V <= 480 V), replicated x4 across
	8	the four MPPTs (2 per 6000XP). This script computes the Path-A CONDUCTORS and BATTERY bank for the
	9	2-inverter topology (the bank busbar feeds two inverter inputs, so no single 250 A cable), plus the
	10	NEC deltas. Conductor sizing reuses the validated size_run() from 03_conductors.
	11
	12	Run: ~/.venvs/prsm-electrical/bin/python scripts/11_pathA.py
	13	"""
	14	import importlib
	15	from common import load_site, require, get, banner, result, dump_result, load_result
	16	from nec_tables import T310_16, std_ocpd_at_least, egc_awg
	17
	18	_c = importlib.import_module("03_conductors") # reuse validated NEC sizing
	19	size_run, report, vdrop_pct = _c.size_run, _c.report, _c.vdrop_pct
	20
	21
	22	def main():
	23	cfg = load_site() # base inverter: = EG4 6000XP (per-unit specs)
	24	banner("11 PATH A — 2x EG4 6000XP (parallel), 28 panels (4x7S), 2-pack bank")
	25	s01 = load_result("01_string") # validated Phase-1 7S string
	26	load = load_result("08_load_actual")
	27	cmp = load_result("10_compare") # computed Path-A production
	28
	29	pmp = require(cfg, "panel.pmp_w"); isc = require(cfg, "panel.isc_a")
	30	imp = require(cfg, "panel.imp_a"); vmp = require(cfg, "panel.vmp_v")
	31	vnom = require(cfg, "battery.nominal_v"); cap_ah = require(cfg, "battery.capacity_ah")
	32	usable_kwh = require(cfg, "battery.usable_kwh"); dod = require(cfg, "battery.dod_design")
	33
	34	# --- topology constants ---
	35	n_inv, npack = 2, 2
	36	n_str, n_series, panels = 4, 7, 28
	37	kw = round(panels * pmp / 1000, 2)
	38	spares = 31 - panels
	39
	40	# per-unit 6000XP specs
	41	ac_unit = require(cfg, "inverter.ac_continuous_w") # 6000
	42	ac_a_unit = require(cfg, "inverter.ac_cont_a_per_leg") # 25
	43	surge_unit = require(cfg, "inverter.ac_surge_w") # 12000 (3.5 s)
	44	eff = require(cfg, "inverter.discharge_eff") # 0.93
	45	inv_dis_unit = require(cfg, "inverter.batt_max_discharge_a") # 140
	46	inv_chg_unit = require(cfg, "inverter.batt_max_charge_a") # 125
	47	pv_unit = require(cfg, "inverter.pv_max_power_w") # 8000
	48	i_in_max = require(cfg, "inverter.pv_max_input_a_per_mppt") # 17
	49	isc_in_max = require(cfg, "inverter.pv_max_isc_a_per_mppt") # 25
	50	voc_ceiling = require(cfg, "inverter.pv_design_voc_ceiling_v") # 480
	51	bms_trip = require(cfg, "battery.bms_discharge_ocp_a") # 150
	52	bms_delay = require(cfg, "battery.bms_ocp_delay_s") # 300
	53	bms_sc = require(cfg, "battery.bms_short_circuit_a") # 300
	54	cell_cont = require(cfg, "battery.cell_continuous_a") # 157
	55
	56	# aggregates
	57	ac_total = n_inv * ac_unit; ac_a_total = n_inv * ac_a_unit
	58	inv_dis_total = n_inv * inv_dis_unit; inv_chg_total = n_inv * inv_chg_unit
	59	pv_usable = n_inv * pv_unit; surge_total = n_inv * surge_unit
	60	runs = get(cfg, "phase2.runs_ft") or cfg["runs_ft"]
	61	tgt = cfg["targets"]
	62	pv_vref = round(n_series * vmp, 1) # 7S Vmp = 307 V
	63
	64	result("config", f"{n_inv}x EG4 6000XP // {panels} panels ({n_str}x{n_series}S) // {npack} packs")
	65	result("array DC / spares held", f"{kw} kW / {spares} panels", "", "3 panels reserved as field spares")
	66	result("string cold Voc (validated 7S)", f"{s01['string_cold_voc_V']} V", "",
	67	f"<= {voc_ceiling} V design (PASS, {voc_ceiling - s01['string_cold_voc_V']:.0f} V margin); same module/ceiling as Phase 1")
	68	result("AC / PV-usable / batt limit", f"{ac_total:.0f}W / {pv_usable:.0f}W / {inv_dis_total:.0f}A",
	69	"", f"2x(6000W / 8000W / 140A); array {kw*1000:.0f}W DC vs {pv_usable:.0f}W usable")
	70
	71	results = {"meta": {"path": "A", "inverters": n_inv, "panels": panels, "spares": spares,
	72	"kw": kw, "strings": n_str, "n_series": n_series,
	73	"string_cold_voc_V": s01["string_cold_voc_V"], "voc_ceiling_V": voc_ceiling,
	74	"array_dc_W": panels * pmp, "pv_usable_W": pv_usable}}
	75
	76	# ---------- conductors ----------
	77	print("\n CONDUCTORS (NEC 690.8 / 310.15 / 240.4 / Ch.9 T8):")
	78	# 1) PV string homeruns (4 strings -> 8 CCC in the trench), worst-case 7S vref
	79	ccc_pv = 2 * n_str
	80	r_pv = size_run("PV string (array->6000XP MPPT, per string)", mode="pv",
	81	current=imp, vref=pv_vref, length_ft=runs["combiner_to_inverter"],
	82	target_pct=tgt["vdrop_dc_pct_max"], ambient_c=40, ccc=ccc_pv, isc=isc, set_ocpd=False)
	83	report(r_pv)
	84	sweep = {L: round(vdrop_pct(r_pv["final_gauge_AWG"], L, imp, pv_vref)[0], 3)
	85	for L in cfg.get("dc_run_sweep_ft", [200])}
	86	result(" DC Vdrop sweep", " / ".join(f"{L}ft:{p}%" for L, p in sweep.items()), "",
	87	f"{r_pv['final_gauge_AWG']}Cu, {ccc_pv} CCC; 1 string/MPPT -> NO source fuse (690.9(A))")
	88	r_pv["vdrop_sweep_pct"] = sweep; r_pv["ccc"] = ccc_pv; r_pv["source_fuse_required"] = False
	89	results["pv_string"] = r_pv
	90	print()
	91
	92	# 2) AC: each 6000XP output (25 A) + the combined feed (50 A) at the parallel busbar
	93	r_ac_unit = size_run("AC per-unit (6000XP->AC combiner)", mode="continuous",
	94	current=ac_a_unit, vref=240.0, length_ft=runs["inverter_to_loads"],
	95	target_pct=tgt["vdrop_ac_pct_max"], ambient_c=30, ccc=2)
	96	report(r_ac_unit)
	97	r_ac_comb = size_run("AC combined (busbar->main panel)", mode="continuous",
	98	current=ac_a_total, vref=240.0, length_ft=runs["inverter_to_loads"],
	99	target_pct=tgt["vdrop_ac_pct_max"], ambient_c=30, ccc=2)
	100	report(r_ac_comb)
	101	results["ac_per_unit"] = r_ac_unit; results["ac_combined"] = r_ac_comb
	102	print()
	103
	104	# 3) Battery bank: busbar fed by 2 packs, feeding 2 inverter inputs.
	105	i_bank = ac_total / eff / vnom # 12 kW from the bank
	106	i_pack = i_bank / npack # per pack
	107	i_inv = i_bank / n_inv # per inverter input
	108	r_pack = size_run("Battery per-pack (pack->busbar)", mode="continuous",
	109	current=i_pack, vref=vnom, length_ft=runs["pack_to_busbar"],
	110	target_pct=tgt["vdrop_battery_pct_max"], ambient_c=30, ccc=2)
	111	report(r_pack)
	112	r_inv = size_run("Battery per-inverter (busbar->6000XP)", mode="continuous",
	113	current=i_inv, vref=vnom, length_ft=runs["inverter_to_battery"],
	114	target_pct=tgt["vdrop_battery_pct_max"], ambient_c=30, ccc=2)
	115	report(r_inv)
	116	result("bank busbar", f"{i_bank:.0f} A (250 A+ rated)", "",
	117	f"2 packs in ({i_pack:.0f}A ea) + 2 inverters out ({i_inv:.0f}A ea) — no single 250A cable")
	118	results["battery_per_pack"] = r_pack; results["battery_per_inverter"] = r_inv
	119	results["bank"] = {"i_bank_A": round(i_bank, 1), "i_pack_A": round(i_pack, 1),
	120	"i_inv_A": round(i_inv, 1), "busbar_A": 250}
	121	print()
	122
	123	# ---------- battery limits / C-rate / surge / autonomy / fusing ----------
	124	print(" BATTERY (limits, C-rate, surge, autonomy, Class-T):")
	125	result("bank vs total inverter limit", f"{i_bank:.1f} / {inv_dis_total}", "A",
	126	f"{'PASS' if i_bank <= inv_dis_total else 'FAIL'} (headroom {inv_dis_total - i_bank:.0f}A, {100*(inv_dis_total-i_bank)/inv_dis_total:.0f}%)")
	127	result("per-inverter vs 6000XP limit", f"{i_inv:.1f} / {inv_dis_unit}", "A",
	128	f"{'PASS' if i_inv <= inv_dis_unit else 'FAIL'} (headroom {inv_dis_unit - i_inv:.0f}A) — same as Phase-1 single pack")
	129	pack_limits = [("JK-BMS OCP (300s)", bms_trip), ("EVE cell 0.5P", cell_cont)]
	130	pb = min(pack_limits, key=lambda x: x[1])
	131	for nm, lim in pack_limits:
	132	result(f"per-pack vs {nm}", f"{i_pack:.1f} / {lim}", "A",
	133	f"{'PASS' if i_pack <= lim else 'FAIL'} ({100*i_pack/lim:.0f}%)")
	134	c_dis = i_pack / cap_ah; c_chg = (inv_chg_total / npack) / cap_ah
	135	result("per-pack C-rate dis / chg", f"{c_dis:.2f}C / {c_chg:.2f}C", "", "<= 0.5C OK")
	136
	137	i_surge_bank = surge_total / eff / vnom; i_surge_pack = i_surge_bank / npack
	138	result("surge (2x12kW, 3.5s)", f"bank {i_surge_bank:.0f}A -> {i_surge_pack:.0f}A/pack", "",
	139	f"> {bms_trip}A OCP but 3.5s << {bms_delay}s delay & < {bms_sc}A SC -> transient, no trip")
	140
	141	bank_kwh = usable_kwh * npack; bank_dod = bank_kwh * dod
	142	avg = load["daily_avg_kwh"]; peak = load["august_peak_kwh_day"]
	143	result("autonomy", f"{bank_dod:.1f} kWh usable -> {bank_dod/avg:.2f} d @avg / {bank_dod/peak:.2f} d @peak",
	144	"", f"{npack} packs @ 80% DoD; generator backfills (same as Path B)")
	145
	146	req_pack = i_pack * 1.25
	147	pca = r_pack["final_gauge_AWG"]; pamp = T310_16[pca][1]; pack_fuse = std_ocpd_at_least(req_pack)
	148	n_classT = npack + n_inv
	149	result("Class-T fusing", f"{n_classT}x {pack_fuse}A (2 packs + 2 inverter inputs)", "",
	150	f">= 125%x{i_pack:.0f}A; <= {pca} cable {pamp}A; each 6000XP battery input fused per its manual")
	151
	152	results["limits"] = {"bank_limit_A": inv_dis_total, "bank_headroom_A": round(inv_dis_total - i_bank, 1),
	153	"per_inv_limit_A": inv_dis_unit, "per_inv_headroom_A": round(inv_dis_unit - i_inv, 1),
	154	"per_pack_binding": pb[0], "per_pack_binding_A": pb[1],
	155	"per_pack_headroom_A": round(pb[1] - i_pack, 1),
	156	"c_dis": round(c_dis, 3), "c_chg": round(c_chg, 3),
	157	"surge_bank_A": round(i_surge_bank, 1), "surge_pack_A": round(i_surge_pack, 1),
	158	"surge_duration_s": 3.5,
	159	"bank_usable_kwh_80dod": round(bank_dod, 2),
	160	"days_avg": round(bank_dod / avg, 2), "days_peak": round(bank_dod / peak, 2),
	161	"classT_fuse_A": pack_fuse, "classT_count": n_classT}
	162
	163	# ---------- production (computed in 10_compare) ----------
	164	A = cmp["path_A"]
	165	result("production (PVWatts, 10)", f"{A['annual']} kWh/yr ({A['pct_load']}% of load)", "",
	166	f"coverage W/S/Aug {A['cov_winter']}/{A['cov_summer']}/{A['cov_aug']}% "
	167	f"(Aug short — battery+gen backfill)")
	168	results["production"] = {"annual_kwh": A["annual"], "pct_load": A["pct_load"],
	169	"cov_winter": A["cov_winter"], "cov_summer": A["cov_summer"],
	170	"cov_aug": A["cov_aug"], "meets_all_seasons": A.get("meets_all_seasons")}
	171
	172	# ---------- NEC deltas vs Path B ----------
	173	checks = [
	174	("690.7", "PASS", f"Max system voltage {s01['string_cold_voc_V']}V (7S) <= 480V design / 500V abs (validated x4 strings)."),
	175	("690.8(A)", "PASS", f"Per string Isc x1.25 = {round(isc*1.25,1)}A; 1 string/MPPT -> Isc {isc}A <= 25A MPPT rating, Imp {imp}A <= 17A input."),
	176	("690.9(A) Ex", "PASS", "NO PV source fusing: exactly 1 string per MPPT (no parallel strings) on either 6000XP."),
	177	("690.9 / 710.15", "PASS", f"AC OCPD: per-unit {r_ac_unit['ocpd_A']}A 2-pole x2 (8AWG) at the parallel busbar; combined {r_ac_comb['ocpd_A']}A (4AWG) to main panel."),
	178	("690.11/690.41(B)", "PASS", "Each 6000XP has integrated PV AFCI + GFDI/isolation (x2 units)."),
	179	("690.12", "VERIFY-AHJ", "Each 6000XP supplies an RSD initiator if required; same ground-mount/AHJ question as Phase 1/Path B."),
	180	("690.13/690.15", "PASS", "Each 6000XP integrated DC disconnect; bank + per-pack + per-inverter disconnects."),
	181	("690.9/480.9/706.31", "PASS", f"{n_classT}x {pack_fuse}A Class-T (2 packs + 2 inverter inputs), 20kAIC, <= 2/0 cable 175A."),
	182	("705", "N/A", "Off-grid. Two inverters PARALLELED (EG4 parallel kit), not utility-interactive; main panel subfed, main breaker locked off."),
	183	("706.7", "PASS", f"2-pack bank on a busbar feeding 2 inverters; bank {i_bank:.0f}A split {i_pack:.0f}A/pack (17% under 150A BMS) and {i_inv:.0f}A/inverter (14A under 140A)."),
	184	("706.x comms", "VERIFY", "TWO JK->Pylontech-CAN links (one per 6000XP) to configure (Swarm §9). Open-loop fallback viable."),
	185	("Redundancy", "NOTE", "N+1: one 6000XP can keep ~half the system (8kW PV / 6kW AC) running if the other fails."),
	186	("690.53/54/56", "ACTION", f"Labels: max system voltage {s01['string_cold_voc_V']}V, 2x inverter output ratings, disconnects, battery hazard."),
	187	]
	188	print("\n NEC DELTAS (Path A vs Path B):")
	189	for sec, st, ev in checks:
	190	print(f" {sec:<20} {st:<11} {ev}")
	191	results["nec_checks"] = [{"section": s, "status": st, "evidence": e} for s, st, e in checks]
	192
	193	dump_result("11_pathA", results)
	194
	195
	196	if __name__ == "__main__":
	197	main()

scripts/README.md +24 -0

…	…	@@ -0,0 +1,24 @@
	1	# scripts/ — grounded calc scaffold
	2
	3	Each script reads `../site.yaml`, prints its inputs + the formula/NEC section it used,
	4	and refuses to emit a number while a required input is still `null`/`CONFIRM`.
	5	They are **stubs with `raise SystemExit("TODO…")`** — the fresh session fills in the
	6	real library calls. Do not delete the TODO until the calc is actually implemented.
	7
	8	Run order:
	9	1. `01_string_sizing.py` — vocmax cold-Voc (NEC 690.7) + pvlib cross-check → modules/string, strings/MPPT. **Binding safety constraint.**
	10	2. `02_production.py` — PVWatts v8 / PySAM annual + winter kWh, per-MPPT power check.
	11	3. `03_conductors.py` — NEC 690.8 ampacity + 310.15 derates → gauges; voltage drop per run; battery Class-T fuse.
	12	4. `04_battery.py` — discharge current vs inverter + JK-BMS limits, C-rate, runtime.
	13	5. `06_schematics.py` — schemdraw SLD + DC-string + battery-wiring → `../artifacts/` (PNG+SVG), using the validated numbers.
	14
	15	`common.py` — `load_site()`, `require()` (hard-fails on unconfirmed inputs), print helpers.
	16
	17	Discipline (from `../CLAUDE.md`): **no number in the final design that didn't come out of one of these scripts.** If you need a value, implement the calc — don't estimate it inline.
	18
	19	Setup:
	20	```
	21	python -m venv .venv && source .venv/bin/activate
	22	pip install -r ../requirements.txt
	23	export NREL_API_KEY=... # developer.nrel.gov (verify host: developer.nlr.gov as of 2026-05-29)
	24	```

scripts/__pycache__/03_conductors.cpython-313.pyc +0 -0

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scripts/__pycache__/common.cpython-313.pyc +0 -0

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scripts/__pycache__/nec_tables.cpython-313.pyc +0 -0

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scripts/common.py +133 -0

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	1	"""Shared helpers for the PRSM electrical-review scripts.
	2
	3	Every script imports `load_site()` and prints its inputs + the formula/NEC section
	4	it used, so results are traceable. No script hard-codes a design number that
	5	belongs in site.yaml. Each calc script also dumps its load-bearing outputs to
	6	artifacts/results/<name>.json so downstream scripts (06_schematics) and the
	7	markdown deliverables pull *computed* numbers, never re-keyed estimates.
	8	"""
	9	from __future__ import annotations
	10	import csv
	11	import json
	12	import pathlib
	13	import sys
	14
	15	try:
	16	import yaml
	17	except ImportError:
	18	sys.exit("pip install pyyaml (add to requirements if missing)")
	19
	20	ROOT = pathlib.Path(__file__).resolve().parent.parent
	21	SITE = ROOT / "site.yaml"
	22	RESULTS = ROOT / "artifacts" / "results"
	23	DATA = ROOT / "data"
	24
	25
	26	def load_usage(name: str = "hardwick_usage.csv") -> list[dict]:
	27	"""Load a saved billing-usage series (newest first) for reuse in calcs.
	28	Skips '#' provenance comment lines. Raw fields net_kwh (int) and bill_amount
	29	(float, USD net cost) come from the ledger; avg_cost_per_kwh is COMPUTED here
	30	(bill_amount / net_kwh) so it never drifts from the raw data.
	31	Source data lives in data/<name>.csv (see its header for provenance)."""
	32	path = DATA / name
	33	with open(path) as f:
	34	lines = [ln for ln in f if ln.strip() and not ln.lstrip().startswith("#")]
	35	rows = list(csv.DictReader(lines))
	36	for r in rows:
	37	r["net_kwh"] = int(r["net_kwh"])
	38	if r.get("bill_amount") not in (None, ""):
	39	r["bill_amount"] = float(r["bill_amount"])
	40	r["avg_cost_per_kwh"] = round(r["bill_amount"] / r["net_kwh"], 4)
	41	return rows
	42
	43
	44	def _deep_merge(base: dict, over: dict) -> dict:
	45	"""Recursively merge `over` onto `base`. Nested dicts merge key-by-key; scalars
	46	and lists REPLACE. Used to overlay the phase2: block onto the base config."""
	47	out = dict(base)
	48	for k, v in over.items():
	49	if isinstance(v, dict) and isinstance(out.get(k), dict):
	50	out[k] = _deep_merge(out[k], v)
	51	else:
	52	out[k] = v
	53	return out
	54
	55
	56	def load_site(phase2: bool = False) -> dict:
	57	"""Load site.yaml. With phase2=True, deep-merge the `phase2:` block over the base
	58	so site.yaml stays the single source and Phase-1 still reproduces untouched.
	59	Adds cfg['_phase'] ('phase1'|'phase2') for downstream branching/suffixing."""
	60	with open(SITE) as f:
	61	cfg = yaml.safe_load(f)
	62	if phase2:
	63	overlay = cfg.get("phase2")
	64	if not overlay:
	65	raise SystemExit("[BLOCKED] --phase2 requested but no phase2: block in site.yaml")
	66	cfg = _deep_merge(cfg, overlay)
	67	cfg["_phase"] = "phase2"
	68	else:
	69	cfg["_phase"] = "phase1"
	70	return cfg
	71
	72
	73	def is_phase2(cfg: dict) -> bool:
	74	return cfg.get("_phase") == "phase2"
	75
	76
	77	def suffix(cfg: dict) -> str:
	78	"""Results-filename suffix so Phase-2 runs don't clobber Phase-1 JSONs."""
	79	return "_phase2" if is_phase2(cfg) else ""
	80
	81
	82	def require(cfg: dict, dotted: str):
	83	"""Fetch a nested key like 'panel.voc_v'; fail loudly if it's still null/CONFIRM."""
	84	node = cfg
	85	for part in dotted.split("."):
	86	node = node[part]
	87	if node is None or (isinstance(node, str) and "CONFIRM" in node):
	88	raise SystemExit(
	89	f"[BLOCKED] site.yaml:{dotted} is unconfirmed ({node!r}). "
	90	"Confirm it from the datasheet/owner before this calc is valid."
	91	)
	92	return node
	93
	94
	95	def get(cfg: dict, dotted: str, default=None):
	96	"""Soft fetch; returns default if missing/null rather than failing."""
	97	node = cfg
	98	try:
	99	for part in dotted.split("."):
	100	node = node[part]
	101	except (KeyError, TypeError):
	102	return default
	103	return default if node is None else node
	104
	105
	106	def banner(title: str):
	107	print("=" * 72)
	108	print(title)
	109	print("=" * 72)
	110
	111
	112	def result(label: str, value, unit: str = "", basis: str = ""):
	113	line = f" {label:<34} {value} {unit}".rstrip()
	114	if basis:
	115	line += f" [{basis}]"
	116	print(line)
	117
	118
	119	def dump_result(name: str, data: dict):
	120	"""Persist a script's computed outputs for downstream consumption."""
	121	RESULTS.mkdir(parents=True, exist_ok=True)
	122	path = RESULTS / f"{name}.json"
	123	with open(path, "w") as f:
	124	json.dump(data, f, indent=2, default=str)
	125	print(f"\n -> wrote {path.relative_to(ROOT)}")
	126
	127
	128	def load_result(name: str) -> dict:
	129	path = RESULTS / f"{name}.json"
	130	if not path.exists():
	131	raise SystemExit(f"[BLOCKED] {path} missing — run the upstream script first.")
	132	with open(path) as f:
	133	return json.load(f)

scripts/nec_tables.py +95 -0

…	…	@@ -0,0 +1,95 @@
	1	"""NEC table data, encoded and cited, for the conductor calcs.
	2	Values transcribed from the National Electrical Code (2023). Copper only.
	3	Each table notes its NEC reference so the design narrative can cite it.
	4	"""
	5
	6	# --- Table 310.16 — Allowable ampacities, copper, not more than 3 CCC, 30C ambient ---
	7	# AWG : (60C, 75C, 90C)
	8	T310_16 = {
	9	"14": (15, 20, 25), "12": (20, 25, 30), "10": (30, 35, 40),
	10	"8": (40, 50, 55), "6": (55, 65, 75), "4": (70, 85, 95),
	11	"3": (85, 100, 110), "2": (95, 115, 130), "1": (110, 130, 145),
	12	"1/0": (125, 150, 170), "2/0": (145, 175, 195), "3/0": (165, 200, 225),
	13	"4/0": (195, 230, 260), "250": (215, 255, 290), "300": (240, 285, 320),
	14	"350": (260, 310, 350), "400": (280, 335, 380), "500": (320, 380, 430),
	15	"600": (355, 420, 475),
	16	}
	17
	18	# --- Chapter 9, Table 8 — DC resistance at 75C, uncoated copper, stranded, ohm/kFT ---
	19	T8_DCRES = {
	20	"14": 3.14, "12": 1.98, "10": 1.24, "8": 0.778, "6": 0.491, "4": 0.308,
	21	"3": 0.245, "2": 0.194, "1": 0.154, "1/0": 0.122, "2/0": 0.0967,
	22	"3/0": 0.0766, "4/0": 0.0608, "250": 0.0515, "300": 0.0429, "350": 0.0367,
	23	"400": 0.0321, "500": 0.0258, "600": 0.0214,
	24	}
	25
	26	# --- Table 310.15(B)(1)(1) — Ambient temp correction, 30C-based, by column ---
	27	# (low, high) inclusive C : (f60, f75, f90)
	28	T310_15B = [
	29	(-100, 10, (1.29, 1.20, 1.15)),
	30	(11, 15, (1.22, 1.15, 1.12)),
	31	(16, 20, (1.15, 1.11, 1.08)),
	32	(21, 25, (1.08, 1.05, 1.04)),
	33	(26, 30, (1.00, 1.00, 1.00)),
	34	(31, 35, (0.91, 0.94, 0.96)),
	35	(36, 40, (0.82, 0.88, 0.91)),
	36	(41, 45, (0.71, 0.82, 0.87)),
	37	(46, 50, (0.58, 0.75, 0.82)),
	38	(51, 55, (0.41, 0.67, 0.76)),
	39	(56, 60, (0.00, 0.58, 0.71)),
	40	]
	41
	42	# --- Table 310.15(C)(1) — Adjustment for >3 current-carrying conductors ---
	43	def fill_factor(ccc: int) -> float:
	44	if ccc <= 3:
	45	return 1.00
	46	if ccc <= 6:
	47	return 0.80
	48	if ccc <= 9:
	49	return 0.70
	50	if ccc <= 20:
	51	return 0.50
	52	if ccc <= 30:
	53	return 0.45
	54	return 0.40
	55
	56	# --- 240.4(D) — Small-conductor max OCPD (copper) ---
	57	T240_4D = {"14": 15, "12": 20, "10": 30}
	58
	59	# --- 240.6(A) — Standard OCPD ampere ratings ---
	60	STD_OCPD = [15, 20, 25, 30, 35, 40, 45, 50, 60, 70, 80, 90, 100, 110, 125,
	61	150, 175, 200, 225, 250, 300, 350, 400, 450, 500]
	62
	63	# --- Table 250.122 — Min equipment grounding conductor by OCPD (copper AWG) ---
	64	T250_122 = [(15, "14"), (20, "12"), (60, "10"), (100, "8"), (200, "6"),
	65	(300, "4"), (400, "3"), (500, "2"), (600, "1")]
	66
	67	AWG_ORDER = ["14", "12", "10", "8", "6", "4", "3", "2", "1",
	68	"1/0", "2/0", "3/0", "4/0", "250", "300", "350", "400", "500", "600"]
	69
	70
	71	def temp_factor(ambient_c: float, col: str) -> float:
	72	idx = {"60": 0, "75": 1, "90": 2}[col]
	73	for lo, hi, facs in T310_15B:
	74	if lo <= ambient_c <= hi:
	75	return facs[idx]
	76	return 0.0
	77
	78
	79	def std_ocpd_at_least(amps: float) -> int:
	80	for r in STD_OCPD:
	81	if r >= amps - 1e-9:
	82	return r
	83	raise ValueError(f"no standard OCPD >= {amps}")
	84
	85
	86	def egc_awg(ocpd_a: float) -> str:
	87	for lim, awg in T250_122:
	88	if ocpd_a <= lim:
	89	return awg
	90	return "1/0"
	91
	92
	93	def max_ocpd_240_4d(awg: str, base_75c: float) -> float:
	94	"""OCPD ceiling for a conductor: small-conductor rule for 14/12/10, else 75C ampacity."""
	95	return T240_4D.get(awg, base_75c)

site.yaml +184 -0

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	1	# PRSM electrical-review — single source of design inputs.
	2	# Values below were CONFIRMED against manufacturer datasheets by the review session
	3	# (2026-06-02) and from the owner for run-lengths + NEC cycle. Each block cites its source.
	4	# Discipline (CLAUDE.md): no number in the final design that a script didn't compute.
	5
	6	site:
	7	name: PRSM off-grid — Northeast Kingdom, VT
	8	latitude: 44.5 # CONFIRM exact site lat (NEK); used for NSRDB pull
	9	longitude: -72.0 # CONFIRM exact site lon
	10	nec_cycle: "2023" # CONFIRMED by owner — VT DPS Division of Fire Safety, NEC 2023 (Art. 690 + 706)
	11	# vocmax pulls NSRDB extreme temps from lat/lon; these are documented fallbacks:
	12	design_low_temp_C: -40 # NEK regional record low (Bloomfield VT -45.6C historic); adversarial
	13	# review upgraded this from -34 to -40 for a defensible NEC 690.7
	14	# "lowest expected ambient". 7S passes at -40 (428V); script takes
	15	# min(this, NSRDB) so a colder NSRDB value would still bind.
	16	design_high_temp_C: 31 # ASHRAE 2% high — drives ampacity ambient correction
	17
	18	panel: # Waaree Elite Series N-Type BiN-08-575 (Grade B "BIN-08-575B")
	19	# SOURCE: Waaree USA datasheet elite-series-bin-08.pdf; cross-checked Missouri W&S, A1SolarStore
	20	model: "Waaree Elite BiN-08-575 — 144 half-cut N-type TOPCon bifacial dual-glass (Grade B)"
	21	pmp_w: 575
	22	voc_v: 52.30 # CONFIRMED (front-side STC). NOT the 108-cell BiN-01 (39.91V).
	23	vmp_v: 43.86 # CONFIRMED
	24	isc_a: 13.87 # CONFIRMED
	25	imp_a: 13.11 # CONFIRMED
	26	voc_tempco_pct_per_C: -0.26 # CONFIRMED (Waaree thermal table) — CRITICAL for cold Voc
	27	isc_tempco_pct_per_C: 0.046 # CONFIRMED
	28	pmax_tempco_pct_per_C: -0.30 # CONFIRMED (used to model Vmp temp behavior w/ pvlib)
	29	max_system_voltage_v: 1500 # CONFIRMED (DC1500V IEC/UL) — module not the binding limit
	30	series_fuse_a: 30 # CONFIRMED max series fuse rating (datasheet)
	31	cells: 144 # 144 half-cut = 72 electrical cells in series
	32	cells_electrical_series: 72
	33	efficiency_pct: 22.26
	34	noct_c: 43
	35	bifaciality: 0.80 # 80% (datasheet)
	36	bifacial_rear_fraction: 0.20 # conservative rear:front irradiance for cold-Voc adder
	37	# (ground-mount albedo); raises open-circuit V — see 01
	38
	39	array:
	40	active_kw_target: 8.0 # ~8 kW now (rest of pallet = future, not wired)
	41	module_count: 14 # 14 x 575W = 8050 W DC — session validates final count/strings
	42	array_type: "fixed_open_rack" # PVWatts array_type=0 (ground mount)
	43	tilt_deg: 50 # CONFIRM with owner (winter-optimized); affects production only
	44	azimuth_deg: 180 # true south
	45
	46	inverter: # EG4 6000XP — SOURCE: EG4-6000XP Manual + Spec Sheet v1.4.4 (eg4electronics.com)
	47	model: "EG4 6000XP"
	48	mppt_count: 2
	49	pv_max_voc_v: 500 # CONFIRMED absolute "do-not-exceed" PV Voc (warranty void above)
	50	pv_design_voc_ceiling_v: 480 # CONFIRMED top of recommended DC input range — cold-Voc design target
	51	mppt_v_min: 120 # CONFIRMED MPPT tracking low
	52	mppt_v_max: 385 # CONFIRMED MPPT tracking high (NOT the Voc ceiling)
	53	pv_startup_v: 100 # CONFIRMED (+/-10)
	54	pv_max_input_a_per_mppt: 17 # CONFIRMED max usable input current per MPPT
	55	pv_max_isc_a_per_mppt: 25 # CONFIRMED Isc rating per MPPT
	56	pv_max_power_w: 8000 # CONFIRMED max usable PV (4000 W per MPPT)
	57	pv_max_power_w_per_mppt: 4000 # CONFIRMED
	58	pv_rec_max_power_w: 10000 # CONFIRMED oversizing allowance
	59	ac_continuous_w: 6000 # CONFIRMED
	60	ac_surge_w: 12000 # CONFIRMED (~3.5 s; 11000 W ~5 s)
	61	ac_voltage: "120/240 split-phase"
	62	ac_cont_a_per_leg: 25 # CONFIRMED (25 A across 240V split-phase)
	63	ac_input_passthrough_a: 50 # CONFIRMED grid/gen bypass
	64	batt_max_charge_a: 125 # CONFIRMED (125 A from PV; 115 A from AC)
	65	batt_max_discharge_a: 140 # CONFIRMED inverter-side battery discharge limit
	66	discharge_eff: 0.93 # CONFIRMED battery->AC discharge efficiency (93%)
	67	mppt_eff: 0.99 # CONFIRMED peak MPPT efficiency
	68	has_dc_disconnect: true # CONFIRMED integrated DC switch per MPPT
	69	has_rapid_shutdown: true # CONFIRMED RSD initiator built in (external E-stop not included)
	70	has_dc_afci: true # CONFIRMED integrated PV AFCI
	71	has_dc_gfdi: true # CONFIRMED PV ground-fault / isolation protection
	72
	73	battery: # Docan S3 16 kWh — SOURCE: Docan listing + JK-PB2A16S20P datasheet + EVE MB31 cell datasheet
	74	model: "Docan S3 16 kWh (51.2V 314Ah, 16S1P EVE MB31, JK-PB2A16S20P 'V19' BMS)"
	75	nominal_v: 51.2
	76	charge_cutoff_v: 58.4 # CONFIRMED (16 x 3.65V)
	77	discharge_cutoff_v: 40 # CONFIRMED (16 x 2.5V) — vendor pack cutoff
	78	capacity_ah: 314 # CONFIRMED (EVE MB31 nominal)
	79	usable_kwh: 16.08 # CONFIRMED (51.2 x 314 / 1000)
	80	config: "16S1P"
	81	cell_type: "EVE MB31 314Ah Grade A LiFePO4"
	82	dod_design: 0.80 # LiFePO4 design depth-of-discharge for runtime
	83	bms_continuous_a: 200 # marketed/JK config max — SOFT (see cell_continuous_a)
	84	bms_recommended_a: 150 # vendor recommended continuous
	85	bms_discharge_ocp_a: 150 # CONFIRMED JK datasheet discharge over-current trip (300 s delay)
	86	bms_ocp_delay_s: 300 # CONFIRMED
	87	bms_short_circuit_a: 300 # CONFIRMED JK short-circuit trip (20 us)
	88	cell_continuous_a: 157 # CONFIRMED EVE MB31 0.5P continuous ceiling (16S1P => pack ceiling)
	89	bms_continuous_charge_a: 150
	90	bms_low_temp_charge_cutoff_c: -20 # CONFIRMED BMS; EVE cell only rated charge >=0C
	91	heating: true # CONFIRMED by owner (2026-06-02): battery heating is PROPANE-based, on a
	92	# separate (non-electrical) budget. Warms cells into the >=0C charge window
	93	# -> pack charges through NEK winter. NO parasitic electrical load on the
	94	# array/battery. Discharge/fuse/cable sizing unaffected. Heating itself out of
	95	# electrical scope (like structure/mounting).
	96	comms: "RS485 x2 + CAN(250k) + RS232 + BT; EG4 closed-loop via JK CAN=Pylontech, 6000XP 'Pylontech 2'"
	97	jk_firmware: "V19 (JK-PB2A16S20P / 16S200A2B)"
	98
	99	# One-way conductor run lengths in FEET — CONFIRMED by owner (2026-06-02).
	100	runs_ft:
	101	array_to_combiner: 0 # No combiner box: EG4 takes one string per MPPT direct (mfr "no combiner needed")
	102	combiner_to_inverter: 200 # owner: 150-250 ft trench; DESIGN at 200, script sweeps 150/200/250
	103	inverter_to_battery: 10 # owner: 5-10 ft; design at 10 (conservative for Vdrop at ~126 A)
	104	inverter_to_loads: 10 # owner: <10 ft AC to subfed main panel (Swarm §17)
	105	dc_run_sweep_ft: [150, 200, 250] # report DC Vdrop across the owner's stated range
	106
	107	targets:
	108	vdrop_dc_pct_max: 2.0
	109	vdrop_battery_pct_max: 1.0
	110	vdrop_ac_pct_max: 2.0
	111
	112	# ============================================================================
	113	# PHASE 2 — FINAL-STATE OVERLAY (full 31-panel pallet, EG4 18kPV, 2-pack bank)
	114	# ----------------------------------------------------------------------------
	115	# Loaded by common.load_site(phase2=True), which DEEP-MERGES this block over the
	116	# base config above. site.yaml stays the single source; the base (Phase-1) values
	117	# are untouched so Phase-1 still reproduces. Scripts run with --phase2 to apply
	118	# this overlay and write *_phase2.json results.
	119	#
	120	# Owner decisions (CONFIRMED 2026-06-03, this session):
	121	# - SELECTED BUILD = PATH A: add a 2nd EG4 6000XP (keep the existing one), 28 panels
	122	# (4x7S), 3 panels held as spares. Computed by scripts/11_pathA.py; deliverables in
	123	# artifacts/phase2/. (Owner picked A for spares + N+1 redundancy + lower cost.)
	124	# - 2x Docan S3 packs (Swarm §6 minimum; 25.7 kWh usable).
	125	# - Battery adjacent to inverter (~10 ft, as Phase-1); 200 ft trench reused.
	126	#
	127	# The phase2: block BELOW encodes PATH B (1x EG4 18kPV) — the RETAINED ALTERNATIVE
	128	# (deliverables in artifacts/phase2-pathB/). Reproduce Path B with: scripts/0N.py --phase2.
	129	# Path A uses the BASE inverter: block (6000XP) x2 via 11_pathA.py (no overlay needed).
	130	# ============================================================================
	131	phase2:
	132	array:
	133	module_count: 31 # full Waaree pallet = 17.825 kW DC (31 x 575 W)
	134	active_kw_target: 17.825
	135
	136	inverter: # EG4 18kPV-12LV — SOURCE: EG4 18kPV Spec Sheet v1.4.3
	137	# (eg4electronics.com/.../EG4-18KPV-12LV-Spec-Sheet.pdf),
	138	# model 18KPV-12LV / IV-12000-HYB-AW; ETL/cULus, UL1741 SA/SB/PCS.
	139	# CONFIRMED from the datasheet this session (2026-06-03).
	140	model: "EG4 18kPV-12LV (48V split-phase hybrid)"
	141	mppt_count: 3 # CONFIRMED
	142	inputs_per_mppt: [2, 1, 1] # CONFIRMED: MPPT1 takes 2 strings, MPPT2/3 one each -> max 4 strings
	143	pv_max_usable_a_per_mppt: [25, 15, 15] # CONFIRMED max USABLE input current per MPPT
	144	pv_max_isc_a_per_mppt: [31, 19, 19] # CONFIRMED max SHORT-CIRCUIT input current per MPPT
	145	pv_max_voc_v: 600 # CONFIRMED absolute DC input ceiling (warranty void / damage above 600)
	146	pv_design_voc_ceiling_v: 550 # CONFIRMED "MPPT voltage high protection" — inverter FAULTS above this;
	147	# the practical cold-Voc design ceiling (the 690.7 hard limit is 600).
	148	mppt_v_min: 140 # CONFIRMED MPPT operating-range low
	149	mppt_v_max: 500 # CONFIRMED MPPT operating-range high
	150	mppt_v_nominal: 360 # CONFIRMED nominal MPPT voltage (best-practice design target)
	151	pv_startup_v: 100 # CONFIRMED unit startup voltage
	152	pv_max_power_w: 18000 # CONFIRMED "maximum utilized solar power"
	153	pv_rec_max_power_w: 21000 # CONFIRMED "recommended maximum solar input"
	154	ac_continuous_w: 12000 # CONFIRMED @240V (10400 W @208V) backup/off-grid output
	155	ac_cont_a: 50 # CONFIRMED max output current
	156	ac_cont_w_per_120v_leg: 8000 # CONFIRMED backup/UPS max continuous line wattage per 120V leg
	157	ac_surge_w_with_pv_5min: 15500 # CONFIRMED peak w/ PV (5 min); 14700 W @10 min
	158	ac_surge_w_no_pv_10min: 13500 # CONFIRMED peak w/o PV (10 min) — the battery-only surge case
	159	ac_input_a: 50 # CONFIRMED max AC input current @240V
	160	ac_input_passthrough_a: 200 # CONFIRMED max AC bypass
	161	gen_bypass_a: 90 # CONFIRMED generator AC bypass
	162	batt_nominal_v: 48 # CONFIRMED nominal battery voltage (range 40-60 V Li)
	163	batt_max_charge_a: 250 # CONFIRMED max charge current
	164	batt_max_discharge_a: 250 # CONFIRMED max discharge current (the binding bank limit at 12 kW)
	165	discharge_eff: 0.94 # CONFIRMED battery->grid max efficiency (94%)
	166	mppt_eff: 0.975 # CONFIRMED max PV->grid efficiency
	167	cec_eff: 0.969 # CONFIRMED CEC weighted efficiency
	168	has_dc_disconnect: true # CONFIRMED integrated PV disconnect
	169	has_rapid_shutdown: true # CONFIRMED RSD initiator (NEC 2020:690.12)
	170	has_dc_afci: true # CONFIRMED PV AFCI (690.11 / UL1699B)
	171	has_dc_gfdi: true # CONFIRMED PV ground-fault monitoring (690.41(B)) + leakage monitor + SPD
	172	comms: "RS485 / Wi-Fi / CAN; closed-loop with EG4 48V & other brands (Docan/JK via CAN profile — confirm)"
	173
	174	battery:
	175	pack_count: 2 # 2x Docan S3 in parallel = 32.16 kWh nameplate / 25.728 kWh usable @80% DoD
	176	bank_busbar: true # packs land on a DC busbar; per-pack Class-T; bank feeds the 18kPV
	177
	178	# One-way run lengths in FEET — CONFIRMED by owner (2026-06-03, this session).
	179	runs_ft:
	180	array_to_combiner: 0 # no combiner: 18kPV takes strings direct to its 4 MPPT inputs
	181	combiner_to_inverter: 200 # remaining 17 panels co-located w/ Phase-1 array; reuse the 150-250 ft trench (design 200)
	182	pack_to_busbar: 5 # each pack -> bank busbar, short
	183	inverter_to_battery: 10 # busbar/bank -> 18kPV, adjacent (~10 ft, as Phase-1); design at 10
	184	inverter_to_loads: 10 # 18kPV AC -> subfed main panel, <10 ft (Swarm §17)