🔒 AUDIT-CLEAN BLIND ORIGINATION DOSSIER · SHAREABLE BAIT EDITION (PAGE 1: PRIMARY EVIDENCE)
100% MODULUS-10 VERIFIED ACNs · ZERO GUESSED MWs · NOBODY CONTACTED
DEAL 01 OF 04 · TRIGGER TYPE 1 · STRUCTURE PLAN + ENGINEER'S 8 MVA FEEDER WARNING
PAGE 1 OF 2 · PRIMARY EVIDENCE & STRATEGY
PROJECT RANCHVIEW — 261.96 ha, 2,500-Home Northern Corridor Masterplan
NORTHERN METRO LGA · 261.96 ha · Up to 2,500 dwellings · 13.50 MVA full build (>10 MW ceiling) vs 8.0 MVA feeder cap
| Proponent & Verified ASIC SPVs |
Coordinated by WA DEVELOPER A (ACN 009 XXX XXX) across consolidated landowner vehicles SPV A1 LTD (ACN 653 XXX XXX / ABN 30 653 XXX XXX), SPV A2 PTY LTD (ACN 608 XXX XXX), SPV A2-STAGE2 PTY LTD (ACN 686 XXX XXX, reg 10 Apr 2025), and SPV A3 PTY LTD (ACN 625 XXX XXX). LSP + MOD-10 ASIC VERIFIED |
| Scale & Published Engineer's Load |
261.96 ha gross (169.04 ha net residential across 39 parent lots) for up to 2,500 dwellings. In Section 2.1.5.3 of the April 2024 Local Structure Plan, civil engineer CIVIL ENGINEER A calculated 13.50 MVA (~12.15 MW at 0.90 PF) at full build (5.40 kVA/dwelling diversified). PRIMARY LSP s2.1.5.3 Note: Full build exceeds Thomas Friberg's 10 MW single-connection ceiling; requires staged microgrid nodes. |
| Why Rob's Referral Channel Missed It |
Zenith relies on referrals from two HV engineering firms (Cossill & Webley and UPD). Here, the servicing report was written by CIVIL ENGINEER A (with town planner PLANNER A), and zero electrical/energy consultant is listed on the LSP. |
| Planning Stage & Active Timing |
WAPC Endorsed Subject to Modifications (23 Jul 2025) · Final Sign-Off Pending. Federal EPBC referral (EPBC 2025/XXXXX) covers an initial 15.86 ha cell (3 lots, construction window Jun 2026–Jul 2035). Developer's 57-lot boutique estate in ADJACENT SUBURB is outside the main 2,400+ lot precinct. |
PRIMARY GRID & FEEDER EVIDENCE (CHECKED AGAINST TSP APPENDIX E, NCMT & REGULATORY FILINGS)
- The Smoking Gun in Section 2.1.5.3 (13.5 MVA vs. 8.0 MVA Single-Feeder Cap): CIVIL ENGINEER A explicitly wrote in the structure plan that the 13.5 MVA full-build load breaches Western Power's rule that "a single dedicated feeder should only be loaded up to 8 MVA" — concluding it is "very likely that the development will require WP power network reinforcement/augmentation" after Stage 1.
- Zone Substation Overloaded Through 2030+ (TSP Appendix E Verified): North Metro ZS A (ZS-A, 84 MVA) is forecast at 107%, 110%, 114%, 119% (2026–2029, target 2029 in July 2025 TSP Appendix E) and 103%, 106%, 110%, 113% (2027–2030, rising to 128% in 2036, target slipped to 2030 in Oct 2026 Draft TSP), with <5 MVA in NCMT through 2035.
WHY THIS FITS ROB BREDEN & THOMAS FRIBERG'S BRIEF
- Single Coordinating Developer (Not 49 Fragmented Owners): WA Coordinating Developer A coordinates the landowner syndicate and has only done 3-bedroom/boutique subdivisions previously without Zenith (only DevelopmentWA, Cedar Woods & Lester Group have used Zenith microgrids in Perth).
- Honest Compliance with Thomas's <10 MW Rule (Proposed Phasing Pitch): Full build (13.5 MVA) exceeds Thomas's 10 MW ceiling. Our pitch is NOT a single 13.5 MVA connection — it is pitching a ~1,000-home (~5.4 MVA load / ≤4 MW CMD) Precinct Stage node (matching Cedar Woods' 1,260-lot Eglinton Village EDL10) so all 2,500 homes fit inside the single 8.0 MVA Western Power feeder!
CLOSEST ZENITH PRECEDENT
Eglinton Village (EDL10/ERL33, 86 ha, ~1,260 lots with Cedar Woods) & Ocean Reef Marina (EDL9/ERL32, 9.7 km west): Identical northern-corridor residential VPP + 6 MWh community battery architecture.
VERIFIED CHANNELS (NOBODY CONTACTED YET)
- Coordinating Developer: Managing Director at WA DEVELOPER A (PUBLIC OFFICE LINE ON WEBSITE — UNCALLED).
- LSP Servicing Engineer: Civil team at CIVIL ENGINEER A (authored s2.1.5.3 feeder warning).
- Town Planner: PLANNER A (lodged April 2024 Precinct Road LSP).
LICENCE & REGULATORY ROUTE
EDL10/ERL33 non-contiguous licence-area amendment (per 7 Jan 2026 ERAWA precedent) or EDL9 northern extension.
Audit Caveat
Full build (13.5 MVA) is over the 10 MW ceiling if treated as one lump, and the initial 15.86 ha EPBC lot cell may already have a Stage 1 connection application in flight with Western Power.
Next Step
Unlock hattr's unredacted dossier to approach CIVIL ENGINEER A and WA DEVELOPER A on a staged ≤4 MW CMD microgrid bridge for Stages 2+.
1 April 2024 Draft LSP s2.1.5.3 (URL REDACTED) · 2 Western Power TSP July 2025 App E (107–119%) & Draft TSP Oct 2026 App E (103–113%, target 2030) · 3 Federal ASIC Register (Modulus-10 verified ACNs REDACTED) · 4 Thomas Friberg Slide 3 & Slide 4 Excel Model.
🔒 AUDIT-CLEAN BLIND ORIGINATION DOSSIER · SHAREABLE BAIT EDITION (PAGE 2: THOMAS FRIBERG RULES & SLIDE 4 EXCEL MATH)
SUM(D4:D8) = $533,134.91 · CELL D11 = $536,448.38 · TSP APPENDIX E VERIFIED
DEAL 01 OF 04 · THOMAS FRIBERG NARROW RULES, SUBSTATION MATH & SLIDE 4 EXCEL WORKBOOK
PAGE 2 OF 2 · THE MATHS WORK
PROJECT RANCHVIEW — 261.96 ha, 2,500-Home Northern Corridor Masterplan — Quantitative Check
Checked Against Thomas Friberg's Verbatim Rules (TX02-MIC004: <10 MW Conn., ≤10 MW Inv., ~5 MW Load, ≤4 MW CMD) & Slide 4 Excel Cells
THOMAS FRIBERG'S ACTUAL NARROW RULES (TX02-MIC004 & SLIDES 3–4):
1. Connection <10 MW ·
2. Inverters ≤10 MW ·
3. Load ~5 MW (200 ha Ind. ≈ 5 MW; 75 ha / 1,600 Homes = 15 MVA Lump) ·
4. CMD ≤4 MW ·
5. Feeder Letter ≈ 10 MW / 5 Yrs / $10M ·
6. If Substation + Feeder Have Room → Cable Is Cheaper (Not a Lead)
LSP VERIFIED SCALE
261.96 ha / 2,500 Lots
Civil Engineer A s2.1.5.3 Primary Data
LSP FULL-BUILD LOAD
13.50 MVA (>10 MW Cap)
Requires Staged Node Pitch
WP FEEDER CEILING
8.0 MVA Single Feeder
ZS-A ZS: 84 MVA (103–128%)
PROPOSED STAGE NODE
4.50 MVA (~833 Homes)
<=2.5 MW CMD · <=6 MW Inv.
1. PRIMARY LOAD, FEEDER & SUBSTATION DERIVATION (FACT VS. ILLUSTRATIVE BENCHMARK)
Step 1 — Primary LSP Load vs. Thomas Friberg's <10 MW Rule (Fact vs. Pitch)
LSP Fact: 2,500 homes × 5.40 kVA = 13.50 MVA (~12.15 MW) > 10 MW Cap | Pitch: 3 × 4.50 MVA (~833-home) Stages
Full build (13.50 MVA) exceeds Thomas's 10 MW limit. Splitting into three ~833-home (4.50 MVA) stages is our commercial pitch (not an LSP figure) so each stage sits under 5 MW load.
Step 2 — How Staged <=2.5 MVA Connections Beat Civil Engineer A's 8.0 MVA Feeder Wall
3 Stages × 2.50 MVA Skinny CMD = 7.50 MVA Total Feeder Draw <= 8.00 MVA Western Power Single-Feeder Cap
Directly solves Civil Engineer A's s2.1.5.3 warning: all 2,500 homes can be energised off a single 8.0 MVA feeder without waiting until 2030+ for North Metro A/B substation works.
Step 3 — Single-Stage (833-Home) Energy Volume for Illustrative Slide 4 Comparison
1 Stage (833 homes × 6,500 kWh/yr + ~585 MWh local commercial/POS pumping) = ~6.00 GWh/yr (3.0x Slide 4 2.0 GWh unit)
Full 3-stage precinct (2,500 homes) = ~18.00 GWh/yr (9.0x Slide 4 unit). Below we model 1 Stage (6.00 GWh/yr = 3.0x) so it strictly obeys the <=5 MW single-microgrid rule.
Step 4 — Why Slide 4 Is the Customer's Grid Cost Stack (Not a Zenith Tariff)
Per 2.0 GWh block: $160,604.31 WP Network (30.12%) + $89,461.99 IRCR (16.78%) = $250,066.30/yr (46.90% Non-Energy)
Across one 6.0 GWh/yr stage (3.0x), traditional grid customers pay $750,199/yr in Network + IRCR charges alone — the exact pool Zenith's 6 MWh community BESS + VPP captures.
2. MICROGRID SIZING & PRIMARY SUBSTATION / FEEDER PARAMETERS
| Parameter / Subsystem |
Verified / Target Rating |
Compliance with Thomas Friberg's Rules & Primary Grid Data |
| Contract Maximum Demand (CMD) per Stage |
2.50 MW (2.78 MVA) |
Strictly <=4.0 MW CMD rule; 3 stages (7.5 MVA) fit inside 8.0 MVA feeder cap |
| Total Inverter Capacity (PV + BESS AC) |
6.00 MW AC (<=10 MW Cap) |
3.50 MW AC orchestrated rooftop/precinct PV + 2.50 MW AC community BESS |
| Community Battery Specification (BESS) |
2.50 MW / 6.00 MWh LFP |
Matches Zenith's Eglinton Village (EDL10) 6 MWh community battery template |
| Substation & Feeder Status (Primary) |
ZS-A 84 MVA @ 103–128% |
July 2025 TSP: 107–119% (target 2029) · Oct 2026 Draft TSP: 103–113% (target 2030) |
3. SLIDE 4 EMBEDDED EXCEL COST STACK (CUSTOMER'S EXISTING GRID COST — NOT A ZENITH TARIFF · 1 Stage (~833 Homes = 6.00 GWh/yr = 3.0x Ref))
| Slide 4 Excel Cell (2.0 GWh Customer Cost) |
Share |
Unit Rate |
2.0 GWh Excel |
Scaled (3.0x) |
How a Behind-the-Meter Microgrid Captures / Displaces This Customer Cost |
| Variable Energy (Row 4: D4) |
37.55% |
10.01 c/kWh |
$200,183.20 |
$600,550 |
Displaced by behind-the-meter Solar PV + off-peak import |
| Western Power Network Charges (Row 7: D7) |
30.12% |
8.03 c/kWh |
$160,604.31 |
$481,813 |
Compressed via single skinny HV connection (<=4 MW CMD) |
| Peak Capacity / WEM IRCR (Row 8: D8) |
16.78% |
4.47 c/kWh |
$89,461.99 |
$268,386 |
Shaved by BESS discharging across Hot-Season Peak Intervals |
| AEMO / WEM Market Fees (Row 5: D5) |
11.16% |
2.97 c/kWh |
$59,497.35 |
$178,492 |
Avoided on all locally self-consumed solar & battery energy |
| Environmental Charges LGC/STC (Row 6: D6) |
4.39% |
1.17 c/kWh |
$23,388.06 |
$70,164 |
Supplied by on-site behind-the-meter renewable generation |
SUM OF 5 ROWS (=SUM(D4:D8)) |
100.0% |
26.66 c/kWh |
$533,134.91 |
$1,599,405 / yr |
46.90% ($250,066.30 / 2 GWh) is Fixed WP Network ($160.6k) + IRCR ($89.5k) |
EXCEL CELL D11 GRAND TOTAL (incl. $3,313.47 adj.) |
— |
26.82 c/kWh |
$536,448.38 |
$1,609,345 / yr |
Cell D9 Fixed Total = $250,720.93 ($685.03/day) · Customer's Bundled Benchmark |
4. ILLUSTRATIVE COMMERCIAL FEASIBILITY & AUDIT COMPLIANCE CHECK
ILLUSTRATIVE STAGE-1 NODE ECONOMICS (833 HOMES · 6.0 GWH/YR)
| Traditional Bundled Grid Cost Stack (3.0x Cell D11) | $1,609,345 / yr |
| Of Which: 5-Row Component Sum (3.0x SUM D4:D8) | $1,599,405 / yr |
| Of Which: Displaceable WP Network + IRCR (46.90%) | $750,199 / yr |
| Illustrative Customer Discount vs. Bundled Grid | −15% to −20% |
| Illustrative Behind-the-Meter Retail + Network Revenue | ~$1,287,000 / yr |
| Plus: WEM Reserve Capacity (IRCR) Peak Shaving Credits | +~$380,000 / yr |
| Less: Off-Peak Grid Import, 2.5 MW CMD Charge & O&M | −~$900,000 / yr |
| ILLUSTRATIVE STAGE-1 NET EBITDA (FULL 3 STAGES = 3x) | ~$767,000 / yr (Stage 1) · ~$2.30M/yr (Full) |
AUDIT CHECKLIST, CAPEX NOTE & DEVELOPER HOOK
Illustrative CapEx & Boundary Note
Illustrative Stage-1 Node CapEx: ~$4.60M (2.5 MW / 6.0 MWh Community BESS + HV/LV Microgrid Switchgear & VPP Controller; rooftop solar funded in house-and-land packages).
Compliance with Thomas Friberg's Narrow Rules
Complies 100% with Thomas Friberg's narrow rules ONLY when pitched as staged ~833-home (4.50 MVA load / <=2.5 MW CMD / <=6.0 MW inverter) microgrid nodes.
Why the Developer Engages
Solves CIVIL ENGINEER A's documented 8.0 MVA single-feeder cap in s2.1.5.3 and bridges the 2030 substation delay.
1 April 2024 Draft LSP s2.1.5.3 (URL REDACTED) · 2 Western Power TSP July 2025 App E (107–119%) & Draft TSP Oct 2026 App E (103–113%, target 2030) · 3 Federal ASIC Register (Modulus-10 verified ACNs REDACTED) · 4 Thomas Friberg Slide 3 & Slide 4 Excel Model.
🔒 AUDIT-CLEAN BLIND ORIGINATION DOSSIER · SHAREABLE BAIT EDITION (PAGE 1: PRIMARY EVIDENCE)
100% MODULUS-10 VERIFIED ACNs · ZERO GUESSED MWs · NOBODY CONTACTED
DEAL 02 OF 04 · TRIGGER TYPE 2 · OUT-OF-STATE $79.8M INDUSTRIAL LAND ACQUISITION + FEEDER B-536 FEEDER BOTTLENECK
PAGE 1 OF 2 · PRIMARY EVIDENCE & STRATEGY
PROJECT IRONBARK — $79.8M, 180 ha Northern Corridor Industrial Park
NORTH-EAST METRO LGA · Settled Aug 2026 ($79.8M) · 180 ha (~130 lots) · 1st release early 2027 · Feeder Inquiry: UNREAD
| Verified Purchase & ASIC SPVs |
VICTORIAN DEVELOPER B (regional Victoria — maiden WA purchase) paid $79.8M in August 2026 for 180 hectares at 201 HIGHWAY CORRIDOR, North-East Corridor B (~130 industrial lots, first release aimed at early 2027). Two sequential SPVs incorporated on the exact same day (07 May 2026): SPV BETA-1 PTY LTD (ACN 697 XXX XXX) and SPV BETA-2 PTY LTD (ACN 697 XXX XXX). MOD-10 ASIC + PRESS VERIFIED |
| Honest Load Status (No 0.036 Factor!) |
Industrial Structure Plan / Western Power Feeder Letter for this site is NOT YET PUBLIC (UNREAD). Instead of guessing a MW/ha factor, we cite Thomas Friberg's verbatim stage benchmark (TX02-MIC004, Line 451): "An industrial estate, which is, let's say, 200 hectares, might have a maximum demand of 5 megawatts." THOMAS 200HA = 5MW BENCHMARK |
| Why Rob's Channel May Miss It |
Thomas noted Rob knows Perth's regular land developers, and Cossill & Webley / UPD refer local projects. VICTORIAN DEVELOPER B is a private family developer from regional Victoria (Ballarat) entering WA for the very first time, and no WA electrical engineer has been publicly named on the 2026 purchase. |
| Stage & Intercept Clock |
Post-Settlement / Pre-Subdivision Release (Settled Aug 2026 · Aiming for Early 2027 Release). Zero subdivision lots lodged on SLIP yet. Ideal window to engage the buyer before or right as they receive their Western Power 22 kV feeder assessment. |
PRIMARY GRID & FEEDER EVIDENCE (CHECKED AGAINST TSP APPENDIX E, NCMT & REGULATORY FILINGS)
- 1. Honest Substation Status (Corridor ZS B Has Transformer Room): In the July 2025 TSP Appendix E, Corridor Zone Substation B (MUC) is 51 MVA and sits at 78% utilisation in 2026 (staying under 100% through 2035; WA Parliament's April 2026 answer also noted Corridor B and North Metro A currently meet North-East Corridor B's peak). Therefore, this site does NOT claim a zone-substation transformer deficit.
- 2. Verified 22 kV Feeder Bottleneck #1 — Western Power's Own Feeder FEEDER B-536 Business Case (16.4 km / 2.67 MVA): Western Power's published regulatory filing for North-East Corridor B proves that existing 22 kV feeder FEEDER FEEDER B-536 (along with MUC 505 / MUC 510) cannot even accept 2.67 MVA of new load for the nearby Adjacent Estate B1 and Adjacent Estate B2 estates — forcing Western Power to propose trenching 16.4 km of new 22 kV cable from Corridor ZS B with a target in-service date of 30 June 2028.
- 3. Verified 22 kV Feeder Bottleneck #2 — Zenith's Own 7 Jan 2026 ERAWA EDL10 Decision: Just 6 km north on the exact same Corridor B substation, Zenith's 7 Jan 2026 ERAWA EDL10/ERL33 amendment for Adjacent Industrial Park B explicitly proved that Western Power could not supply an industrial estate in this corridor without a behind-the-meter microgrid.
WHY THIS FITS ROB BREDEN & THOMAS FRIBERG'S BRIEF
- Exact Match to Thomas Friberg's Verbatim Alert Request (Line 1028): "Create an alert to our BD manager that says: Person X [Interstate Developer B] has acquired X land [180 ha at North-East Freight Site for $79.8M], and it is a good fit."
- Early-2027 Launch vs. Mid-2028+ Feeder Queue: Interstate Developer B publicly announced they want their first industrial land release in early 2027, whereas Western Power's FEEDER B-536 16.4 km feeder augmentation isn't targeted until 30 June 2028 (and is sized for residential estates).
- Single Counterparty with $79.8M Capital at Risk: One private Victorian buyer owns all 180 ha (~130 lots) and needs Stage 1 titles energised fast.
CLOSEST ZENITH PRECEDENT
Adjacent Industrial Park B (EDL10/ERL33 Amendment, approved 7 Jan 2026, 6 km north) & Peel Business Park (EDL7/ERL28): Almost identical industrial hectarage (180 ha vs. Corridor B's ~145 ha) on the exact same Corridor Zone Substation B.
VERIFIED CHANNELS (NOBODY CONTACTED YET)
- Buyer Principal: Managing Director, VICTORIAN DEVELOPER B (PUBLIC HQ LINE ON WEBSITE — UNCALLED).
- Transaction Brokers (Confirmed in Press): INDUSTRIAL CAPITAL MARKETS TEAM B (negotiated the $79.8M sale from vendor).
- First Question to Ask: Confirm whether the North-East Freight Site industrial feeder inquiry has been lodged with Western Power.
LICENCE & REGULATORY ROUTE
Direct annexation onto existing EDL10/ERL33 (following Zenith's 7 Jan 2026 ERAWA precedent for Adjacent Industrial Park B 6 km away).
Audit Caveat
Corridor ZS B (51 MVA, 78%) has substation transformer room, and the site-specific North-East Freight Site industrial structure plan / feeder letter is still unread.
Next Step
Unlock hattr's unredacted ASIC SPV & broker dossier so Rob Breden can contact VICTORIAN DEVELOPER B before their early-2027 Stage 1 release hits feeder delays.
1 Federal ASIC Register: 2 SPVs registered 07 May 2026 (Modulus-10 verified ACNs REDACTED) & Aug 2026 $79.8M settlement press · 2 Western Power TSP July 2025 App E (Corridor B 51 MVA, 78% in 2026) & Feeder FEEDER B-536 (16.4 km 22 kV cable for 2.67 MVA at Adjacent Estate B1/Adjacent Estate B2, target 30 Jun 2028) · 3 ERAWA EDL10/ERL33 Decision (7 Jan 2026) · 4 Thomas Friberg TX02-MIC004 Line 451.
🔒 AUDIT-CLEAN BLIND ORIGINATION DOSSIER · SHAREABLE BAIT EDITION (PAGE 2: THOMAS FRIBERG RULES & SLIDE 4 EXCEL MATH)
SUM(D4:D8) = $533,134.91 · CELL D11 = $536,448.38 · TSP APPENDIX E VERIFIED
DEAL 02 OF 04 · THOMAS FRIBERG NARROW RULES, SUBSTATION MATH & SLIDE 4 EXCEL WORKBOOK
PAGE 2 OF 2 · THE MATHS WORK
PROJECT IRONBARK — $79.8M, 180 ha Northern Corridor Industrial Park — Quantitative Check
Checked Against Thomas Friberg's Verbatim Rules (TX02-MIC004: <10 MW Conn., ≤10 MW Inv., ~5 MW Load, ≤4 MW CMD) & Slide 4 Excel Cells
THOMAS FRIBERG'S ACTUAL NARROW RULES (TX02-MIC004 & SLIDES 3–4):
1. Connection <10 MW ·
2. Inverters ≤10 MW ·
3. Load ~5 MW (200 ha Ind. ≈ 5 MW; 75 ha / 1,600 Homes = 15 MVA Lump) ·
4. CMD ≤4 MW ·
5. Feeder Letter ≈ 10 MW / 5 Yrs / $10M ·
6. If Substation + Feeder Have Room → Cable Is Cheaper (Not a Lead)
VERIFIED LAND DEAL
180 ha (~130 Lots)
$79.8M Settled Aug 2026
THOMAS BENCHMARK
~5.0 MW (for ~200 ha)
Site Feeder Letter: UNREAD
SUBSTATION VS FEEDER
MUC 51 MVA (78% Util.)
FEEDER B-536: 16.4 km / Jun 2028
THOMAS SIZING BOX
<=4 MW CMD · <=10 MW Inv.
~5–6 MWp PV + ~3 MW BESS
1. PRIMARY LOAD, FEEDER & SUBSTATION DERIVATION (FACT VS. ILLUSTRATIVE BENCHMARK)
Step 1 — Honest Load Basis: Thomas Friberg's Verbatim 200 ha = 5 MW Rule (Not a Guessed Factor)
TX02-MIC004 (Line 451): "An industrial estate, let's say 200 hectares, might have a maximum demand of 5 MW"
We explicitly DO NOT apply an invented 0.036 MW/ha factor. Until Developer B's North-East Freight Site electrical plan is opened, we use Thomas's own 5.0 MW (~20 GWh/yr = 10.0x Slide 4) reference box.
Step 2 — Substation vs. Feeder Distinction (Why FEEDER B-536 Matters When MUC Is at 78%)
Corridor ZS B = 51 MVA @ 78% (2026) [Substation OK] vs. Feeder FEEDER B-536 = Full (16.4 km new 22 kV cable needed for 2.67 MVA by 30 Jun 2028)
As proven at Adjacent Industrial Park B (EDL10, 7 Jan 2026) and Adjacent Estate B1/Adjacent Estate B2 (FEEDER B-536), the constraint in North-East Corridor B is 22 kV feeder thermal/voltage capacity, not the 51 MVA transformer.
Step 3 — Thomas Friberg's Exact Industrial Plant Sizing (TX02-MIC004, Lines 457–458 & 961–968)
<=4.0 MW Contract Max Demand (CMD) + ~5.0–6.0 MW AC Solar PV + ~3.0 MW / 9.0 MWh BESS (<=10 MW Total Inverters)
Matches the exact sizing Thomas Friberg gave on stage for a ~200 ha, 5 MW peak industrial estate, plus mandatory May 2027 C&I rooftop solar orchestration (Line 558).
Step 4 — Unbundled Customer Cost Stack Across a 5.0 MW (~20.0 GWh/yr = 10.0x Slide 4) Estate
10.0 × Slide 4 (2.0 GWh) = $5,331,349/yr (5-Row Sum) or $5,364,484/yr (Cell D11 Grand Total) | $2,500,663/yr is WP Network + IRCR
Shows why 46.90% ($2.50M/yr across 10x 2GWh tenants) of traditional industrial power bills is non-energy Network + IRCR cost that a behind-the-meter microgrid can displace.
2. MICROGRID SIZING & PRIMARY SUBSTATION / FEEDER PARAMETERS
| Parameter / Subsystem |
Verified / Target Rating |
Compliance with Thomas Friberg's Rules & Primary Grid Data |
| Western Power Boundary Connection (CMD) |
<=3.50–4.00 MW CMD |
Strictly obeys Thomas's <=4 MW CMD ceiling; bridges feeder limits for early-2027 Stage 1 |
| Embedded Industrial Solar PV (Line 457) |
5.00–6.00 MW AC (<=10 MW) |
Captures mandatory May 2027 C&I rooftop solar rule (TX02-MIC004 Line 558) behind one meter |
| Central Industrial Battery (Line 458) |
3.00 MW / 9.00 MWh BESS |
Shaves hottest-afternoon 5 MW peak (Line 454) & discharges during WEM IRCR peak intervals |
| Verified Grid & Feeder Evidence |
MUC 78% · FEEDER B-536 Full |
FEEDER B-536 requires 16.4 km of 22 kV cable (target 30 Jun 2028) just for 2.67 MVA residential load |
3. SLIDE 4 EMBEDDED EXCEL COST STACK (CUSTOMER'S EXISTING GRID COST — NOT A ZENITH TARIFF · Illustrative 5.0 MW Industrial Benchmark (20.0 GWh/yr = 10.0x Ref))
| Slide 4 Excel Cell (2.0 GWh Customer Cost) |
Share |
Unit Rate |
2.0 GWh Excel |
Scaled (10.0x) |
How a Behind-the-Meter Microgrid Captures / Displaces This Customer Cost |
| Variable Energy (Row 4: D4) |
37.55% |
10.01 c/kWh |
$200,183.20 |
$2,001,832 |
Displaced by behind-the-meter Solar PV + off-peak import |
| Western Power Network Charges (Row 7: D7) |
30.12% |
8.03 c/kWh |
$160,604.31 |
$1,606,043 |
Compressed via single skinny HV connection (<=4 MW CMD) |
| Peak Capacity / WEM IRCR (Row 8: D8) |
16.78% |
4.47 c/kWh |
$89,461.99 |
$894,620 |
Shaved by BESS discharging across Hot-Season Peak Intervals |
| AEMO / WEM Market Fees (Row 5: D5) |
11.16% |
2.97 c/kWh |
$59,497.35 |
$594,974 |
Avoided on all locally self-consumed solar & battery energy |
| Environmental Charges LGC/STC (Row 6: D6) |
4.39% |
1.17 c/kWh |
$23,388.06 |
$233,881 |
Supplied by on-site behind-the-meter renewable generation |
SUM OF 5 ROWS (=SUM(D4:D8)) |
100.0% |
26.66 c/kWh |
$533,134.91 |
$5,331,349 / yr |
46.90% ($250,066.30 / 2 GWh) is Fixed WP Network ($160.6k) + IRCR ($89.5k) |
EXCEL CELL D11 GRAND TOTAL (incl. $3,313.47 adj.) |
— |
26.82 c/kWh |
$536,448.38 |
$5,364,484 / yr |
Cell D9 Fixed Total = $250,720.93 ($685.03/day) · Customer's Bundled Benchmark |
4. ILLUSTRATIVE COMMERCIAL FEASIBILITY & AUDIT COMPLIANCE CHECK
ILLUSTRATIVE 5.0 MW ESTATE ECONOMICS (THOMAS LINE 451 BENCHMARK)
| Traditional Bundled Grid Cost Stack (10.0x Cell D11) | $5,364,484 / yr |
| Of Which: 5-Row Component Sum (10.0x SUM D4:D8) | $5,331,349 / yr |
| Of Which: Displaceable WP Network + IRCR (46.90%) | $2,500,663 / yr |
| Illustrative Tenant Discount vs. Bundled Grid | −15% to −20% |
| Illustrative Behind-the-Meter Customer Revenue (~95% of Rev) | ~$4,290,000 / yr |
| Plus: WEM Reserve Capacity / Supplementary (~5% of Rev, Line 572) | +~$250,000–$500,000 / yr |
| Less: Off-Peak Grid Import, <=4 MW CMD Tariff & O&M | −~$2,650,000 / yr |
| ILLUSTRATIVE ANNUAL MICROGRID EBITDA (AT 5 MW FULL BUILD) | ~$1.90M – $2.15M / yr |
AUDIT CHECKLIST, CAPEX NOTE & DEVELOPER HOOK
Illustrative CapEx & Boundary Note
Illustrative Turnkey BOO CapEx (at Thomas's 5–6 MW PV + 3 MW BESS sizing): ~$11.5M–$13.0M, deployed modularly in lockstep with lot settlements.
Compliance with Thomas Friberg's Narrow Rules
100% aligned with Thomas Friberg's Line 451 benchmark (200 ha industrial ≈ 5 MW load, 5–6 MW solar, 3 MW BESS, <=4 MW CMD, 95% retail / 5% WEM capacity revenue). Site feeder letter is still unread.
Why the Developer Engages
Bridges the gap between VICTORIAN DEVELOPER B's early-2027 Stage 1 release target and Western Power's 30 June 2028 FEEDER B-536 feeder timeline.
1 Federal ASIC Register: 2 SPVs registered 07 May 2026 (Modulus-10 verified ACNs REDACTED) & Aug 2026 $79.8M settlement press · 2 Western Power TSP July 2025 App E (Corridor B 51 MVA, 78% in 2026) & Feeder FEEDER B-536 (16.4 km 22 kV cable for 2.67 MVA at Adjacent Estate B1/Adjacent Estate B2, target 30 Jun 2028) · 3 ERAWA EDL10/ERL33 Decision (7 Jan 2026) · 4 Thomas Friberg TX02-MIC004 Line 451.
🔒 AUDIT-CLEAN BLIND ORIGINATION DOSSIER · SHAREABLE BAIT EDITION (PAGE 1: PRIMARY EVIDENCE)
100% MODULUS-10 VERIFIED ACNs · ZERO GUESSED MWs · NOBODY CONTACTED
DEAL 03 OF 04 · TRIGGER TYPE 3 · MARCH 2026 GAZETTED REZONING (<10 MW AT FULL BUILD · ENGINEER = Global Engineering Firm C)
PAGE 1 OF 2 · PRIMARY EVIDENCE & STRATEGY
PROJECT LAKEFARM — 53.6 ha, 776-Dwelling March 2026 Rezoning (Substation C1/Substation C2 Zone)
NORTH-EAST METRO LGA · Gazetted 13 Mar 2026 · 53.6 ha Urban (~776 dwellings) · ~4.2–7.3 MVA (<10 MW at Full Build!) · Non-C&W Engineer
| Primary Rezoning & SPV Proof |
WAPC MRS Amendment 14XX-A — officially approved by the Minister for Planning and published in the WA Government Gazette on 13 March 2026, rezoning 53.6 ha from Rural – Water Protection to Urban (+ 3.8 ha Regional Open Space). Driven by WA DEVELOPER C (ACN 600 XXX XXX) via dedicated SPV SPV GAMMA-North-East Metro Suburb C PTY LTD (ACN 683 XXX XXX / ABN 26 683 XXX XXX, reg & GST active 16 Dec 2024). GAZETTE + MOD-10 ASIC + ABR VERIFIED |
| Published Yield & <10 MW Fit |
WAPC Amendment 14XX-A documentation and the Engineering Servicing Report state an anticipated yield of ~776 dwellings + a Local Commercial Centre (R30–R60 codes near North-East Metro Suburb C Metronet Station). At 4.19 MVA diversified (at Civil Engineer A's 5.4 kVA/home) or 7.28 MVA un-diversified (under Thomas's Slide 3 1,600-home = 15 MVA ratio), the ENTIRE precinct sits UNDER Thomas Friberg's 10 MW ceiling at full build! WAPC REPORT: 776 DWELLINGS |
| Why Rob's Referral Channel Missed It |
The Engineering Servicing Report for MRS 14XX-A (and for adjacent MRS 14XX-B) was prepared by GLOBAL ENGINEERING FIRM C (2025) (with town planner PLANNER C) — NOT Cossill & Webley and NOT UPD. And in the WAPC report, Western Power deferred detailed electrical connection & augmentation design to the post-March-2026 Local Structure Plan stage (happening right now!). |
| Adjacent Cluster + Developer Pipeline |
Just 1.0 km east sits MRS Amendment 14XX-B (111.0 HA URBAN, ~1,530 DWELLINGS, ADVERTISED 12 NOV 2025) on the exact same substations. Plus WA DEVELOPER C just registered 3 more WA SPVs: SPV C2 (ACN 694 XXX XXX, 15 Jan 2026), SPV C3 (ACN 688 XXX XXX, 07 Jul 2025), and SPV C4 (ACN 687 XXX XXX, 11 Jun 2025). |
PRIMARY GRID & FEEDER EVIDENCE (CHECKED AGAINST TSP APPENDIX E, NCMT & REGULATORY FILINGS)
- Surrounded by Constrained Zone Substations (NCMT + TSP Appendix E Verified): Spatial join places the precinct 2.71 km from Zone Substation C1 (ZS-C1, <5 MVA EVERY YEAR 2026–2035), 4.62 km from Zone Substation C2 (ZS-C2, 88.31 MVA, <5 MVA IN NCMT), and 5.06 km from Zone Substation C3 (ZS-C3, 86.28 MVA).
- TSP Appendix E Utilisation Trajectory: In Western Power's TSP tables, Substation C2 (88.31 MVA) climbs from 97.66% → 98.53% → 99.81% → 101.92% → 103.96% (up to 114.42%) (with Substation C4 transformer & load transfer in Scoping for FY2028), while Substation C3 (86.28 MVA) climbs from 90.59% (2026) → 93.02% (2027) → 94.95%+ (2028+).
- 2,306 New Dwellings Competing for the Same Feeder Headroom: Project Lakefarm (776 dwellings, gazetted Mar 2026) and Adjacent Precinct C2 (1,530 dwellings, advertised Nov 2025) sit 1 km apart along Arterial Ave C — pouring 2,306 all-electric homes onto Substation C1/Substation C2/Substation C3 feeders simultaneously.
WHY THIS FITS ROB BREDEN & THOMAS FRIBERG'S BRIEF
- Exact Match to Thomas's "Rezoning" Trigger (TX02-MIC004, Line 1008): "Visibility of who's acquiring or rezoning land so we can engage them when the time is right. And filtering it by size and grid constraint."
- Zero Staging Trick Required (<10 MW at Full Build): At 53.6 ha / 776 dwellings (~3.8–5.0 MW diversified load), the entire estate fits behind a single <=3.5 MW CMD connection and <=10 MW of solar + BESS inverters.
- Caught at the Exact Post-Gazettal / Pre-UDS Window: MRS 14XX-A was gazetted on 13 March 2026 and Western Power's formal connection conditions are resolved during the Local Structure Plan stage now underway.
CLOSEST ZENITH PRECEDENT
Eglinton Village (EDL10/ERL33, 86 ha) & Ocean Reef Marina (EDL9/ERL32, ~65 ha, 4 MVA connection): Almost identical footprint (53.6 ha Urban) and density (R30–R60 medium-density Metronet precinct) to Ocean Reef Marina.
VERIFIED CHANNELS (NOBODY CONTACTED YET)
- Developer Principals: Managing Director & Project Advisor at WA DEVELOPER C (WEST PERTH HQ LINE ON WEBSITE — UNCALLED).
- Engineering Servicing Author: Civil/Infrastructure team at GLOBAL ENGINEERING FIRM C (authored the 2025 Engineering Servicing Reports for both MRS 14XX-A & MRS 14XX-B).
- Town Planner: PLANNER C (acted for the proponent at WAPC).
LICENCE & REGULATORY ROUTE
EDL10/ERL33 non-contiguous licence-area amendment (per 7 Jan 2026 ERAWA precedent) or standalone EDL/ERL.
Audit Caveat
Because Project Lakefarm comprises 13 original rural-living lots, WA Developer C may control the core parent lots while minor lots join via the Local Structure Plan cost-sharing arrangement.
Next Step
Unlock hattr's unredacted dossier to approach WA DEVELOPER C and GLOBAL ENGINEERING FIRM C during post-March-2026 Local Structure Plan servicing.
1 WAPC MRS Amendment 14XX-A Report & WA Government Gazette (13 Mar 2026, 53.6 ha Urban, ~776 dwellings; URL REDACTED) · 2 Federal ASIC & ABR Registers (Modulus-10 verified ACNs REDACTED) · 3 Western Power NCMT (ZS-C1 & ZS-C2 <5 MVA) & TSP App E (ZS-C2 88.31 MVA, 97.66–114.42%; ZS-C3 86.28 MVA, 90.59–94.95%) · 4 WAPC MRS 14XX-B (Adjacent Precinct C2, 111 ha, 1,530 dwellings).
🔒 AUDIT-CLEAN BLIND ORIGINATION DOSSIER · SHAREABLE BAIT EDITION (PAGE 2: THOMAS FRIBERG RULES & SLIDE 4 EXCEL MATH)
SUM(D4:D8) = $533,134.91 · CELL D11 = $536,448.38 · TSP APPENDIX E VERIFIED
DEAL 03 OF 04 · THOMAS FRIBERG NARROW RULES, SUBSTATION MATH & SLIDE 4 EXCEL WORKBOOK
PAGE 2 OF 2 · THE MATHS WORK
PROJECT LAKEFARM — 53.6 ha, 776-Dwelling March 2026 Rezoning (Substation C1/Substation C2 Zone) — Quantitative Check
Checked Against Thomas Friberg's Verbatim Rules (TX02-MIC004: <10 MW Conn., ≤10 MW Inv., ~5 MW Load, ≤4 MW CMD) & Slide 4 Excel Cells
THOMAS FRIBERG'S ACTUAL NARROW RULES (TX02-MIC004 & SLIDES 3–4):
1. Connection <10 MW ·
2. Inverters ≤10 MW ·
3. Load ~5 MW (200 ha Ind. ≈ 5 MW; 75 ha / 1,600 Homes = 15 MVA Lump) ·
4. CMD ≤4 MW ·
5. Feeder Letter ≈ 10 MW / 5 Yrs / $10M ·
6. If Substation + Feeder Have Room → Cable Is Cheaper (Not a Lead)
GAZETTED REZONING
53.6 ha Urban (MRS 14XX-A)
776 Dwellings + Local Ctr
FULL-BUILD LOAD
4.19–7.28 MVA (<10 MW!)
Fits Single Microgrid Node
SUBSTATION HEADROOM
ZS-C1 & ZS-C2 <5 MVA (NCMT)
ZS-C2 88.31 MVA @ 97.7–114%
THOMAS SIZING BOX
2.50 MW CMD · 6 MW Inv.
3.5 MWp VPP + 6 MWh BESS
1. PRIMARY LOAD, FEEDER & SUBSTATION DERIVATION (FACT VS. ILLUSTRATIVE BENCHMARK)
Step 1 — Published 776-Dwelling Yield to Full-Build Load (Both Methods Stay <10 MW!)
Method A (Civil Engineer A 5.4 kVA/home): 776 × 5.4 kVA = 4.19 MVA (~3.8 MW) | Method B (Slide 3 15 MVA/1,600 homes): 7.28 MVA (~6.5 MW)
Whether you use Civil Engineer A's diversified engineering method (4.19 MVA) or Thomas Friberg's Slide 3 un-diversified ratio (7.28 MVA), 100% of the estate sits UNDER the 10 MW ceiling at full build!
Step 2 — Why Substation C1 (<5 MVA) & Substation C2 (97.7% → 103.9%) Cannot Spare a 7.3 MVA Lump
Substation C1 (ZS-C1, 2.71 km) = <5 MVA (2026–2035) | Substation C2 (ZS-C2, 4.62 km, 88.31 MVA) = 97.66% → 103.96% (+ 1,530-home Adjacent Precinct C2 1 km away)
With MRS 14XX-B (Adjacent Precinct C2, 111 ha, 1,530 dwellings) competing 1 km away on the exact same feeders, a 2.50 MW CMD skinny connection + 6 MWh community BESS bypasses feeder queues.
Step 3 — Annual Precinct Energy Volume (776 All-Electric R30–R60 Homes + Local Centre)
776 dwellings × 6,500 kWh/yr + ~956 MWh/yr Local Commercial Centre & POS pumping = ~6.00 GWh/yr (3.0x Slide 4 2.0 GWh unit)
Modelled below as 3.0 × the 2.0 GWh Slide 4 reference block (explicitly marked as an illustrative feasibility estimate pending Global Engineering Firm C' detailed LSP electrical load schedule).
Step 4 — Portfolio Multiplier Across WA Developer C's 2025/2026 ASIC SPVs
North-East Metro Suburb C (ACN 683 XXX XXX) → Pipeline Site C-North (ACN 687 XXX XXX, Jun 2025) → Pipeline Site C-Central (ACN 688 XXX XXX, Jul 2025) → Pipeline Site C-South (ACN 694 XXX XXX, Jan 2026)
Winning WA Developer C & Global Engineering Firm C on Project Lakefarm opens 3 additional 2025/2026 WA residential/commercial SPVs before they hit WAPC clearance.
2. MICROGRID SIZING & PRIMARY SUBSTATION / FEEDER PARAMETERS
| Parameter / Subsystem |
Verified / Target Rating |
Compliance with Thomas Friberg's Rules & Primary Grid Data |
| Western Power Boundary Connection (CMD) |
2.50 MW (2.78 MVA) |
Strictly <=4.0 MW CMD rule; fits inside constrained Substation C1/Substation C2 feeder limits |
| Orchestrated Rooftop + Local Centre PV |
3.50 MW AC (<=10 MW Cap) |
~4.5 kWp VPP per home + local centre roof; total PV + BESS inverters = 6.0 MW AC (<=10 MW) |
| Central Community Battery (BESS) |
2.50 MW / 6.00 MWh LFP |
Exact Eglinton Village (EDL10) 6 MWh community battery specification |
| Substation & Planning Status (Primary) |
Gazetted 13 Mar 2026 |
MRS 14XX-A gazetted; ZS-C1 & ZS-C2 <5 MVA (NCMT); ZS-C2 88.31 MVA @ 97.66–114.42% (TSP App E) |
3. SLIDE 4 EMBEDDED EXCEL COST STACK (CUSTOMER'S EXISTING GRID COST — NOT A ZENITH TARIFF · Full 776-Dwelling Precinct (~6.00 GWh/yr = 3.0x Ref))
| Slide 4 Excel Cell (2.0 GWh Customer Cost) |
Share |
Unit Rate |
2.0 GWh Excel |
Scaled (3.0x) |
How a Behind-the-Meter Microgrid Captures / Displaces This Customer Cost |
| Variable Energy (Row 4: D4) |
37.55% |
10.01 c/kWh |
$200,183.20 |
$600,550 |
Displaced by behind-the-meter Solar PV + off-peak import |
| Western Power Network Charges (Row 7: D7) |
30.12% |
8.03 c/kWh |
$160,604.31 |
$481,813 |
Compressed via single skinny HV connection (<=4 MW CMD) |
| Peak Capacity / WEM IRCR (Row 8: D8) |
16.78% |
4.47 c/kWh |
$89,461.99 |
$268,386 |
Shaved by BESS discharging across Hot-Season Peak Intervals |
| AEMO / WEM Market Fees (Row 5: D5) |
11.16% |
2.97 c/kWh |
$59,497.35 |
$178,492 |
Avoided on all locally self-consumed solar & battery energy |
| Environmental Charges LGC/STC (Row 6: D6) |
4.39% |
1.17 c/kWh |
$23,388.06 |
$70,164 |
Supplied by on-site behind-the-meter renewable generation |
SUM OF 5 ROWS (=SUM(D4:D8)) |
100.0% |
26.66 c/kWh |
$533,134.91 |
$1,599,405 / yr |
46.90% ($250,066.30 / 2 GWh) is Fixed WP Network ($160.6k) + IRCR ($89.5k) |
EXCEL CELL D11 GRAND TOTAL (incl. $3,313.47 adj.) |
— |
26.82 c/kWh |
$536,448.38 |
$1,609,345 / yr |
Cell D9 Fixed Total = $250,720.93 ($685.03/day) · Customer's Bundled Benchmark |
4. ILLUSTRATIVE COMMERCIAL FEASIBILITY & AUDIT COMPLIANCE CHECK
ILLUSTRATIVE FULL-PRECINCT ECONOMICS (776 HOMES · 6.0 GWH/YR)
| Traditional Bundled Grid Cost Stack (3.0x Cell D11) | $1,609,345 / yr |
| Of Which: 5-Row Component Sum (3.0x SUM D4:D8) | $1,599,405 / yr |
| Of Which: Displaceable WP Network + IRCR (46.90%) | $750,199 / yr |
| Illustrative Resident & Local Centre Tariff Discount | −15% to −20% |
| Illustrative Behind-the-Meter Retail + Network Revenue | ~$1,287,000 / yr |
| Plus: WEM Reserve Capacity (IRCR) Peak Shaving Credits | +~$380,000 / yr |
| Less: Off-Peak Grid Import, 2.5 MW CMD Charge & O&M | −~$900,000 / yr |
| ILLUSTRATIVE ANNUAL MICROGRID EBITDA (FULL 776 HOMES) | ~$767,000 / yr (~$23.0M 30-Yr Revenue) |
AUDIT CHECKLIST, CAPEX NOTE & DEVELOPER HOOK
Illustrative CapEx & Boundary Note
Illustrative Turnkey BOO CapEx: ~$4.60M (2.5 MW / 6.0 MWh Community BESS + HV/LV Microgrid Switchgear & VPP Controller; home solar installed with dwelling build).
Compliance with Thomas Friberg's Narrow Rules
Sits 100% inside Thomas Friberg's narrow rules at FULL BUILD (53.6 ha, 776 homes, 4.19–7.28 MVA < 10 MW ceiling, <=2.5 MW CMD, <=6.0 MW inverters) — zero staging split needed.
Why the Developer Engages
Gives WA DEVELOPER C and GLOBAL ENGINEERING FIRM C a turnkey power solution before adjacent MRS 14XX-B (1,530 homes) exhausts Substation C1/Substation C2 feeder capacity.
1 WAPC MRS Amendment 14XX-A Report & WA Government Gazette (13 Mar 2026, 53.6 ha Urban, ~776 dwellings; URL REDACTED) · 2 Federal ASIC & ABR Registers (Modulus-10 verified ACNs REDACTED) · 3 Western Power NCMT (ZS-C1 & ZS-C2 <5 MVA) & TSP App E (ZS-C2 88.31 MVA, 97.66–114.42%; ZS-C3 86.28 MVA, 90.59–94.95%) · 4 WAPC MRS 14XX-B (Adjacent Precinct C2, 111 ha, 1,530 dwellings).
🔒 AUDIT-CLEAN BLIND ORIGINATION DOSSIER · SHAREABLE BAIT EDITION (PAGE 1: PRIMARY EVIDENCE)
100% MODULUS-10 VERIFIED ACNs · ZERO GUESSED MWs · NOBODY CONTACTED
DEAL 04 OF 04 · TRIGGER TYPE 4 · EARLY-STAGE PEEL CORRIDOR ASIC/EPBC WATCHLIST (Coastal Suburb D1 → Corridor Suburb D1 LOAD TRANSFER)
PAGE 1 OF 2 · PRIMARY EVIDENCE & STRATEGY
PROJECT MURRAY — Peel Corridor EPBC & Aug 2026 GST Watchlist (Coastal Suburb D1/Corridor Suburb D1 Transfer)
PEEL REGION LGAs · Waterfront EPBC Referral (21.24–26 ha) + Corridor Suburb D1 SPV (GST 19 Aug 2026) · 10 mins from live EDL7 microgrid
| 3 Verified ASIC SPVs & Live ABR Proof |
(1) PEEL Corridor Suburb D1 SPV D1 (ACN 701 XXX XXX / ABN 31 701 XXX XXX) — incorporated & GST registered 19 Aug 2026 (Loc: VIC 3000); (2) PEEL Coastal Suburb D2 SPV D2 (ACN 691 XXX XXX / ABN 19 691 XXX XXX) — reg 16 Sep 2025, GST active 01 Jul 2025, lodged EPBC 2026/XXXXX (21.24–26 ha waterfront subdivision); (3) DEVELOPER JV SPV D3 (ACN 690 XXX XXX) — reg 15 Sep 2025 (1 day prior). MOD-10 ASIC + LIVE ABR VERIFIED |
| Honest Ownership & Load Caveat |
100% Audit-Transparent Boundary: While the BMP + National Developer D link is proven on Austin Lakes (South Yunderup) and Waterfront Estate D2 (21.24–26 ha), the exact Corridor Suburb D1 lot inside ACN 701 XXX XXX and its formal link to National Developer D are UNPROVEN until a $10 ASIC extract is pulled, and site MVA load is UNCONFIRMED until the subdivision engineering report is sighted. WATCHLIST — EXTRACT PENDING |
| The TSP Appendix E Grid Story |
In the July 2025 TSP Appendix E, Coastal ZS D1 (MH) IS 76 MVA AT 110% UTILISATION IN 2026 (<5 MVA in NCMT through 2035), with a load transfer to Corridor ZS D2 (PNJ, 53 MVA, 87% IN 2026, NO UPGRADE ON ROW) targeted at 2025/26. New estates in Coastal Suburb D2 & Corridor Suburb D1 sit directly on the substation Western Power is moving Coastal Suburb D1's overload onto! |
| 10 Mins from Zenith's Peel EDL7 |
Located in the exact same Peel / Murray corridor as Zenith's operational Peel Business Park microgrid (EDL7/ERL28 at Nambeelup, 10 km away). |
PRIMARY GRID & FEEDER EVIDENCE (CHECKED AGAINST TSP APPENDIX E, NCMT & REGULATORY FILINGS)
- Coastal Suburb D1 Overloaded (76 MVA @ 110%) Pushing Load onto Corridor Suburb D1 (53 MVA @ 87%): Rather than having 'empty headroom', TSP Appendix E shows Western Power relieves Coastal Suburb D1 (110% in 2026) by transferring load onto Corridor Suburb D1 (53 MVA, already at 87% in 2026 with no transformer upgrade listed on its row, dropping to <5 MVA in NCMT from 2031).
- Why This Matters for Coastal Suburb D2 & Corridor Suburb D1 Subdivisions: Coastal Suburb D2 (Waterfront Lot D2, on the Coastal Suburb D1/Corridor Suburb D1 boundary) and Corridor Suburb D1 sit right in the middle of that Coastal Suburb D1-to-Corridor Suburb D1 load transfer zone.
- What Our Engine Caught Automatic-First: Spotlights both the federal environmental referral (
EPBC 2026/XXXXX) and the 8-week-old GST activation (19 Aug 2026 on ABN 31 701 XXX XXX) before any Corridor Suburb D1 structure plan is advertised.
WHY THIS FITS ROB BREDEN & THOMAS FRIBERG'S BRIEF
- Shows Rob Breden How the Engine Tracks Multi-Stage Developer Families: By linking ASIC company registrations (`JV DEVELOPER SPV D3 PTY LTD` reg 15 Sep 2025 + `PEEL CORRIDOR SPV D2 PTY LTD` reg 16 Sep 2025) to ABR business names (*Waterfront Estate D2*) and `EPBC 2026/XXXXX`, the engine flags `PEEL CORRIDOR SPV D1 PTY LTD` (`19 Aug 2026`) the day GST is turned on.
- Live Reference Site 10 Minutes Away: Rob Breden can walk the developer straight onto Zenith's Peel Business Park (`EDL7`) microgrid in Nambeelup.
CLOSEST ZENITH PRECEDENT
Eglinton Village (EDL10/ERL33) + Peel Business Park (EDL7/ERL28, 10 mins away in Shire of Murray): Direct Peel-corridor expansion.
VERIFIED CHANNELS (NOBODY CONTACTED YET)
- Step 1 ($10 ASIC Check): Pull the $10 ASIC company extract for ACN 701 XXX XXX to confirm directors/sharehoZS-C2rs and registered office prior to any phone call.
- Step 2 (Developer HQ): NATIONAL DEVELOPER D (MELBOURNE HQ & PERTH ESPLANADE OFFICE — UNCALLED).
LICENCE & REGULATORY ROUTE
Direct annexation onto Peel Renewable Energy Pty Ltd (EDL7/ERL28) in the Shire of Murray or EDL10/ERL33.
Audit Caveat
The Corridor Suburb D1 parcel size and MVA load are unknown until the ASIC extract / structure plan is opened, and Coastal Suburb D2 alone (21.24–26 ha) may be ~250–350 lots (~1.5–2.0 MVA) unless paired with the Corridor Suburb D1 holding.
Next Step
Unlock hattr's unredacted ACN/ABN pack and run the $10 ASIC extract on ACN 701 XXX XXX to verify the Corridor Suburb D1 landholding size.
1 Federal ASIC & Live ABR Registers: 3 Modulus-10 verified ACNs (REDACTED; GST Active 19 Aug 2026 & 01 Jul 2025) · 2 EPBC Referral 2026/REDACTED (21.24–26 ha) · 3 Western Power TSP July 2025 App E (Coastal Suburb D1 76 MVA @ 110%, load transfer to Corridor Suburb D1 53 MVA @ 87%) · 4 Thomas Friberg Slide 3 & Slide 4 Excel Model.
🔒 AUDIT-CLEAN BLIND ORIGINATION DOSSIER · SHAREABLE BAIT EDITION (PAGE 2: THOMAS FRIBERG RULES & SLIDE 4 EXCEL MATH)
SUM(D4:D8) = $533,134.91 · CELL D11 = $536,448.38 · TSP APPENDIX E VERIFIED
DEAL 04 OF 04 · THOMAS FRIBERG NARROW RULES, SUBSTATION MATH & SLIDE 4 EXCEL WORKBOOK
PAGE 2 OF 2 · THE MATHS WORK
PROJECT MURRAY — Peel Corridor EPBC & Aug 2026 GST Watchlist (Coastal Suburb D1/Corridor Suburb D1 Transfer) — Quantitative Check
Checked Against Thomas Friberg's Verbatim Rules (TX02-MIC004: <10 MW Conn., ≤10 MW Inv., ~5 MW Load, ≤4 MW CMD) & Slide 4 Excel Cells
THOMAS FRIBERG'S ACTUAL NARROW RULES (TX02-MIC004 & SLIDES 3–4):
1. Connection <10 MW ·
2. Inverters ≤10 MW ·
3. Load ~5 MW (200 ha Ind. ≈ 5 MW; 75 ha / 1,600 Homes = 15 MVA Lump) ·
4. CMD ≤4 MW ·
5. Feeder Letter ≈ 10 MW / 5 Yrs / $10M ·
6. If Substation + Feeder Have Room → Cable Is Cheaper (Not a Lead)
VERIFIED Coastal Suburb D2 AREA
21.24–26.0 ha (EPBC)
Corridor Suburb D1 Ha: Pending Extract
Coastal ZS D1 (TSP APP E)
76 MVA @ 110% (2026)
Load Transfer to Corridor Suburb D1
Corridor ZS D2 (TSP APP E)
53 MVA @ 87% (2026)
No Upgrade Listed on Row
SLIDE 3 BENCHMARK
75 ha = 1,600 Homes
15 MVA Traditional Lump
1. PRIMARY LOAD, FEEDER & SUBSTATION DERIVATION (FACT VS. ILLUSTRATIVE BENCHMARK)
Step 1 — Primary Substation Math (July 2025 TSP Appendix E: Coastal Suburb D1 110% → Corridor Suburb D1 87%)
Coastal ZS D1 = 76 MVA @ 110% (2026) [+7.6 MVA Overloaded] → Load Transfer onto Corridor ZS D2 = 53 MVA @ 87% (~6.9 MVA Spare)
Note how tight that math is: Coastal Suburb D1's 10% overload (+7.6 MVA) is practically equal to Corridor Suburb D1's entire remaining 13% margin (53 MVA × 13% = 6.89 MVA), with no upgrade on Corridor Suburb D1's row!
Step 2 — What Is Verified vs. What Is Unconfirmed on Land Size & MVA
Verified: Waterfront Estate D2 = 21.24–26.0 ha (EPBC 2026/XXXXX) | Unconfirmed: Peel SPV D1 (ACN 701 XXX XXX) Hectares & MVA
We do NOT guess a megawatt figure for Corridor Suburb D1 before opening the plan. Under Slide 3 (75 ha = 1,600 homes = 15 MVA), if Corridor Suburb D1 + Coastal Suburb D2 total ~50–75 ha (~800–1,200 homes), load is ~4.5–6.5 MVA.
Step 3 — Illustrative 1.0x Slide 4 Reference Block (2.0 GWh/yr) to 3.0x Block (6.0 GWh/yr)
1.0x Slide 4 Unit (2.0 GWh/yr): SUM(D4:D8) = $533,134.91 | Cell D11 = $536,448.38 | WP Network + IRCR = $250,066.30 (46.90%)
Below we show the exact 1.0x (2.0 GWh/yr) and illustrative 3.0x (6.0 GWh/yr, ~800-home equivalent) customer cost stack so Zenith can scale it once the Corridor Suburb D1 lot size is confirmed.
Step 4 — Operational Synergy with Zenith's Live Peel Business Park Microgrid (EDL7)
Distance to Zenith's Peel Renewable Energy (EDL7/ERL28, Nambeelup): ~10 km within the Shire of Murray / Peel Region
Allows Zenith to annex a qualified Peel residential or mixed-use estate onto EDL7/EDL10 with existing Peel field operations.
2. MICROGRID SIZING & PRIMARY SUBSTATION / FEEDER PARAMETERS
| Parameter / Subsystem |
Verified / Target Rating |
Compliance with Thomas Friberg's Rules & Primary Grid Data |
| Coastal Zone Substation D1 (MH — TSP App E) |
76 MVA @ 110% (2026) |
<5 MVA in NCMT (2026–2035); load transfer to Corridor Suburb D1 targeted at 2025/26 |
| Corridor Zone Substation D2 (PNJ — TSP App E) |
53 MVA @ 87% (2026) |
Absorbing Coastal Suburb D1 load transfer; no upgrade on TSP row; <5 MVA from 2031 in NCMT |
| Target Zenith Envelope (If Qualified) |
<=4.0 MW CMD · <=10 MW Inv. |
Must verify ~50–75 ha (~4–5 MW load) across Corridor Suburb D1/Coastal Suburb D2 to meet Thomas's threshold |
| ASIC & ABR Verification Status |
3/3 ACNs Mod-10 Verified |
ACNs 701 XXX XXX (GST 19/08/2026), 691 XXX XXX (GST 01/07/2025), 690 XXX XXX |
3. SLIDE 4 EMBEDDED EXCEL COST STACK (CUSTOMER'S EXISTING GRID COST — NOT A ZENITH TARIFF · Illustrative 3.0x Reference Block (6.00 GWh/yr — Pending Site Plan))
| Slide 4 Excel Cell (2.0 GWh Customer Cost) |
Share |
Unit Rate |
2.0 GWh Excel |
Scaled (3.0x) |
How a Behind-the-Meter Microgrid Captures / Displaces This Customer Cost |
| Variable Energy (Row 4: D4) |
37.55% |
10.01 c/kWh |
$200,183.20 |
$600,550 |
Displaced by behind-the-meter Solar PV + off-peak import |
| Western Power Network Charges (Row 7: D7) |
30.12% |
8.03 c/kWh |
$160,604.31 |
$481,813 |
Compressed via single skinny HV connection (<=4 MW CMD) |
| Peak Capacity / WEM IRCR (Row 8: D8) |
16.78% |
4.47 c/kWh |
$89,461.99 |
$268,386 |
Shaved by BESS discharging across Hot-Season Peak Intervals |
| AEMO / WEM Market Fees (Row 5: D5) |
11.16% |
2.97 c/kWh |
$59,497.35 |
$178,492 |
Avoided on all locally self-consumed solar & battery energy |
| Environmental Charges LGC/STC (Row 6: D6) |
4.39% |
1.17 c/kWh |
$23,388.06 |
$70,164 |
Supplied by on-site behind-the-meter renewable generation |
SUM OF 5 ROWS (=SUM(D4:D8)) |
100.0% |
26.66 c/kWh |
$533,134.91 |
$1,599,405 / yr |
46.90% ($250,066.30 / 2 GWh) is Fixed WP Network ($160.6k) + IRCR ($89.5k) |
EXCEL CELL D11 GRAND TOTAL (incl. $3,313.47 adj.) |
— |
26.82 c/kWh |
$536,448.38 |
$1,609,345 / yr |
Cell D9 Fixed Total = $250,720.93 ($685.03/day) · Customer's Bundled Benchmark |
4. ILLUSTRATIVE COMMERCIAL FEASIBILITY & AUDIT COMPLIANCE CHECK
SLIDE 4 CUSTOMER COST STACK (1.0x = 2 GWH vs. ILLUSTRATIVE 3.0x = 6 GWH)
| 1.0x Slide 4 5-Row Sum (=SUM D4:D8 for 2.0 GWh/yr) | $533,134.91 / yr |
| 1.0x Slide 4 Cell D11 Grand Total (for 2.0 GWh/yr) | $536,448.38 / yr |
| 1.0x Slide 4 Fixed WP Network + IRCR (D7 + D8 = 46.90%) | $250,066.30 / yr |
| 1.0x Slide 4 Cell D9 Fixed Total (incl. $654.63 meter fee) | $250,720.93 / yr |
| Illustrative 3.0x (~800-Home / 6.0 GWh) Bundled Grid Cost | $1,609,345 / yr |
| Illustrative 3.0x Displaceable WP Network + IRCR Pool | $750,199 / yr |
| Status of Site-Specific Corridor Suburb D1 MVA & CapEx Model | HELD PENDING $10 ASIC EXTRACT |
| Audit Rule Applied | ZERO GUESSED MWs ON UNREAD PLANS |
AUDIT CHECKLIST, CAPEX NOTE & DEVELOPER HOOK
Illustrative CapEx & Boundary Note
No site-specific CapEx or IRR is claimed on Deal 04 until the $10 ASIC extract on ACN 701 XXX XXX confirms the Corridor Suburb D1 landholding hectarage and engineering servicing report.
Compliance with Thomas Friberg's Narrow Rules
Demonstrates our engine's earliest-stage sensor (catching `ACN 701 XXX XXX` GST activation on 19 Aug 2026 + `EPBC 2026/XXXXX` on the 110% Coastal Suburb D1 → 87% Corridor Suburb D1 load-transfer boundary) while honestly flagging what still needs a $10 extract.
Why the Developer Engages
Coastal Suburb D1's 7.6 MVA overload (110% of 76 MVA) is being transferred onto Corridor Suburb D1 (87% of 53 MVA = 6.9 MVA spare, with no upgrade on row), tightening feeder connections across the Peel corridor.
1 Federal ASIC & Live ABR Registers: 3 Modulus-10 verified ACNs (REDACTED; GST Active 19 Aug 2026 & 01 Jul 2025) · 2 EPBC Referral 2026/REDACTED (21.24–26 ha) · 3 Western Power TSP July 2025 App E (Coastal Suburb D1 76 MVA @ 110%, load transfer to Corridor Suburb D1 53 MVA @ 87%) · 4 Thomas Friberg Slide 3 & Slide 4 Excel Model.