The 230 kW third-party-owned linear generator on your digester biogas is locked in a 14-year PPA through 2037. The third-party owner keeps the 30% federal credit, the depreciation, and the operating margin. PG&E industrial rates are up 35–45% cumulative since 2023. The §48E credit cliff hits 12/31/33. CIP 25708 — your $19M electrical rebuild — is already in design phase. The window to flip the structural ownership is closing on three clocks at once.
All numbers are preliminary projections built on public data + industry midpoints. Specific OEM and EPC partners, peer-customer references, and firm vendor pricing are not disclosed on this page — they sit behind a mutual NDA + non-circumvention at Phase 2 entry. Every dollar figure, MW size, $/kWh rate, GHG ton, and timeline date is subject to material revision based on (a) the free Phase-1 14-day memo using NapaSan-confirmed data, (b) firm vendor quotes received in Phase 2 bake-off, (c) site walk findings, (d) CPRA-confirmed utility data, (e) BAAQMD + PG&E Rule 21(M) interconnect study outcomes, and (f) NapaSan Board procurement decisions. This page is not an offer.
“CIP 25708 — WWTP Electrical Improvements: $682K planning + $19.0M total ($5.0M FY26/27, $7.24M FY27/28, $7.45M future). Replaces motor control centers installed in the 1970s–1990s and adds a looped power-distribution architecture. Already in Design phase.”
This is not BCal's roadmap. It's NapaSan's own capital plan, in writing, in the design phase right now. The marginal cost of designing a customer-owned FC + BESS tie-in onto the new looped distribution is a fraction of retrofitting it after construction. Phase 1 (COD ~2029) lands inside the CIP 25708 window — and captures the full §48E credit before the 2034 cliff. Plus: the FY25/26 budget already funds an internal renewable-energy re-evaluation. BCal does that diligence for free in 14 days.
Three phases. Two decades. One construction-start deadline. Each milestone below is a contractual checkpoint, not a marketing slide.
230 kW third-party linear generator on your digester gas. 14-yr PPA through 2037. The third-party developer captures the 30% ITC + depreciation + operating margin. Recip cogen just absorbed $620K rebuild.
2-hour site walk. CPRA-confirmed utility + biogas data hand-off. Free 14-day Phase-1 memo (no NDA, no procurement action) lands.
LOI within 5 business days of site walk. NapaSan Board approval. Mutual NDA + non-circumvention signed. EPC + OEM bake-off begins.
CEQA, BAAQMD Reg 9-9, PG&E Rule 21/21M, biogas cleanup skid integration. CIP 25708 looped-distribution tie-in design locked.
1.2–1.5 MW customer-owned fuel cell + 1 MW / 4 MWh LFP battery. Eliminates the ~880 kW nighttime PG&E import. RES-BCT credits route to every other NapaSan PG&E meter.
Aligns with NapaSan recycled-water expansion + Climate Mitigation Plan. Inside the §48E full-credit window. Modular — only if demand math supports.
Per OBBBA July 2025: construction-start by this date locks in 30% §48E ITC + 30% §6417 Direct Pay. 2034 = 75%. 2035 = 50%. 2036 = zero.
Aging 415 kW recip retired (post-$620K band-aid). ~32+ tons/yr NOx eliminated. ~5,000–7,000 MTCO2e/yr Scope 1 eliminated. BAAQMD compliance load drops.
14-yr third-party PPA terminates. Option to consolidate the 230 kW onto the customer-owned platform. Operating margin + RES-BCT routing fully on NapaSan's side.
100% digester gas + directed-biogas / RNG. Climate Mitigation Plan complete. RES-BCT credit-routing extended to all NapaSan-owned PG&E accounts.
We can't read which one is keeping you up at night — but each below is independently documented in NapaSan's own records. The case for moving inside the §48E window doesn't depend on which one matters most.
The 230 kW third-party-owned unit on your digester gas is locked in through 2037. The third-party developer keeps the 30% ITC, the depreciation, and the spread vs PG&E retail. Customer-owned flips this. §6417 Direct Pay is the unlock for special districts.
Public PR · Jun 2023 · Napa Valley Register$19M electrical rebuild in design now. 1970s–1990s MCCs replaced with looped distribution. BTM tie-in costs minimized when designed in — 2–3× more expensive to retrofit later. Once-in-30-years window.
May 20, 2026 Board Packet · 10-yr CIPBoard RES 25-001: $700K emergency mid-year amendment for chemicals + electricity (May 2025). PG&E industrial rates +35–45% cumulative since 2023. The 415 kW recip just absorbed a $620K band-aid rebuild — major-service interval clock ticking.
RES 25-001 · April 2024 Board PacketThe existing 230 kW third-party deal was Phase 1 of the Climate Mitigation Plan. Recycled-water rates rising 8.5%/yr through 2031 — every dollar saved on PG&E is a dollar your Board doesn't have to ask ratepayers for. Plus MCE Deep Green tier signals premium-for-green appetite.
CWEA · MCE · NVR rate coverageThe honest framing: we don't know which of these tipped you into the call — and we don't need to. Phase 1 memo (free, 14 days, no NDA) re-runs the math against your actual rate class, gas-flow records, and CIP 25708 design package. Whichever pressure matters most to you, the numbers point to the same construction-start window.
Cash to the general fund. Risk off NapaSan's balance sheet. Strategic optionality on fuel, policy, and the routing of bill credits across every meter you own.
NapaSan is a political subdivision of California, eligible for §6417 Direct Pay under Treasury final regulations (March 2024). 30% of qualified project basis returns as cash to the general fund within 12–18 months of COD. No tax-equity partner. No structuring drag. Cash to softened the next recycled-water rate ask.
Anchor EPC + 2–3 California EPCs bid every scope. 20-yr LTSA on availability + heat rate + NOx. NERC CIP-013-3 + IEC 62443 cyber designed in (founder background: 20+ yrs hardware security in semiconductors). BAAQMD + CEQA + Rule 21(M) all carried by BCal. Owner's-rep model — NapaSan contracts directly with OEM and EPC.
Public-agency-only RES-BCT routes surplus bill credits at retail rate to every NapaSan PG&E account — lift stations, pump stations, admin, recycled-water sites. PPA structures structurally cannot. Plus: black-start islanding for the WWTP under SB X1-2 critical-infrastructure regs. RNG-flex roadmap from digester biogas to directed-biogas to RNG-blend.
We don't manufacture cells, build EPCs, or operate plants. We assemble the multi-vendor, multi-credit, multi-regulatory transaction — and stand behind it. Owner's-rep model: you contract directly with proven counterparties.
Direct Pay for political subdivisions is procedurally distinct from corporate ITC monetization. We've structured the eligibility memo + IRS filing pathway with bond counsel review. No tax-equity partner needed.
Peer references in California wastewater fuel-cell deployments at the 1.2–2.8 MW scale with biogas + RNG fuel, customer-owned and PPA structures. Project names, OEM identities, and operational data shared under executed mutual NDA.
Four chemistry families (SOFC · PAFC · microturbine · MCFC carbonate) evaluated per your gas flow + size. Anchor EPC + 2–3 California EPCs bid every scope. OEM and EPC identities disclosed under mutual NDA at Phase 2 entry.
Public-agency-only program (AB 512, 5 MW cap per generating account). We've modeled the credit-routing math across multi-meter portfolios. Phase 1 memo maps it across every NapaSan PG&E account you own.
NERC CIP-013-3 + IEC 62443 designed in, not bolted on. EPA / CISA / WaterISAC pressure on wastewater controls is rising — won't be optional in 2027. Founder background: 20+ years hardware security in semiconductors.
OEM manufactures cells. EPC builds. LTSA operates. BCal orchestrates the multi-vendor, multi-credit, multi-regulatory transaction. Open-book on every line item — no markup hidden in EPC pricing. Milestone-paid developer fee.
Your 65% self-gen headline is an annual average. The night is where the PG&E line item lives. Phase 1 closes the night.
Plant load ~1.53 MW average across ~13 GWh/yr. Recip + 3rd-party PPA unit + solar cover ~65% on annual average; remaining ~35% from MCE Deep Green + PG&E import — concentrated overnight when solar is dark.
Open-book waterfall. Every line item is traceable to a vendor benchmark, regulatory filing, or industry midpoint. Direct Pay rebate flows to the general fund within 12–18 months of COD. Final dollars confirmed against your data in Phase 1.
Structured to align BCal payment with NapaSan outcomes. Floor case lands well under 10%; full fee is only paid if every execution gate is hit on schedule. The largest tranche only triggers when the §6417 Direct Pay rebate actually arrives in NapaSan's general fund — BCal's incentive is locked to the cash showing up where you can see it.
Floor case ($0.7–1.1M, ~5–5.5%): NapaSan keeps more if execution slips. Max case ($1.4–2.4M, ~10–11%): every milestone hit, every credit captured, COD on-schedule, Direct Pay landed. Open-book pricing on every other line in the waterfall — BCal earns through best-of-market sourcing, not through hidden markup in EPC pricing.
SGIP and LCFS excluded from base case (SGIP permanently closed Dec 31, 2025 per CPUC D.25-12-003; LCFS stationary BTM = $0, transportation-only pathway). Tax-exempt revenue bond financing at ~4.0–4.6% (AA NapaSan-class, mid-May 2026 muni market) on net $9.5–14.3M.
PG&E industrial rates have risen ~35–45% since 2023. BCal escalation is much lower (debt service flat, LTSA 2.5%/yr, RNG ~3%/yr). The gap widens every year. Drag the slider to test sensitivity.
Cash-positive from Y1. LCOE crossover already inside Year 1 once C3 + C5 stack. Real value: Direct Pay cash, rate hedge across 20-yr life, PSPS resiliency.
Status quo isn't free. Continuing the recip + paying PG&E + the forced 2034–35 capital cycle (at degraded §48E percentages) costs more than BCal in absolute dollars — and locks NapaSan into BAAQMD compliance risk.
The honest framing: BCal Phase 1 is materially cheaper than status quo + forced replacement over 20 years. Plus: ~32+ tons/yr NOx eliminated by recip retirement, $3.9–6.1M Direct Pay cash to general fund, RES-BCT credit routing to every NapaSan meter, and a locked rate hedge against a PG&E + MCE generation cost curve that's already up 35–45% since 2023. Status quo also locks NapaSan into BAAQMD Reg 9-9 SCR retrofit pressure on the recip's next major mod.
By recip retirement (target ~2034), NapaSan eliminates the dirtiest emissions source on the site. BAAQMD compliance load drops. Air-quality CEQA findings shift to net beneficial.
FC ultra-low NOx eliminates BAAQMD Reg 9-9 BACT exposure entirely. Air-quality CEQA findings shift from significant-and-unavoidable to net beneficial. Cogen retirement could also generate banked NOx emission reduction credits under BAAQMD banking rules — speculative but high-potential given the magnitude of the source.
Our current numbers carry a ±20% confidence band (we used only public data). Each item NapaSan shares — via CPRA or NDA — narrows the band. Items 1–4 are CPRA; 5–8 trigger the mutual NDA + non-circumvention at Phase 2 entry. Model is fully transparent — toggle items below.
NapaSan keeps optionality. Path O captures the §6417 cash and the RES-BCT routing. Path P is the procurement fallback if balance-sheet posture argues for ESA — though at BCal's required PPA pricing, it is materially worse for NapaSan.
Customer-owned. Dual-fed digester biogas + PG&E common-carrier RNG. Tied into CIP 25708 looped MV distribution. Bake-off across four chemistry families (SOFC / PAFC / microturbine / MCFC carbonate) — OEM resolved at Phase 2 entry under NDA.
Plus B-20 max-demand reduction · plus RES-BCT credits routed to every NapaSan PG&E meter · plus $3.9–6.1M Direct Pay to general fund within 18 mo.
Modular — only if NapaSan demand growth + recycled-water expansion math supports. Construction-start before 12/31/33 to capture full §48E credit.
Phase 2 of the same plan that the existing 3rd-party deal was Phase 1 of. Not a critique of the prior decision — a continuation of it.
Aging 415 kW recip decommissioned post-band-aid rebuild. June 2037: the existing 14-yr third-party PPA terminates; option to consolidate the 230 kW onto the customer-owned platform.
BAAQMD Reg 9-9 BACT exposure removed. Air-quality CEQA findings shift to net beneficial. RES-BCT routing extended across all NapaSan PG&E accounts.
Each step is a deliverable, not a meeting. Step 4 (LOI) puts NapaSan inside the §48E construction-start window with maximum schedule slack.
BCal-funded · public data only. Tariff modeling, load profile, sizing sensitivity, CIP 25708 alignment, full incentive stack, RES-BCT routing math, tech + EPC shortlist.
See data room2 hours on-site. Soscol central electrical room. CIP 25708 design package. Biogas piping. Proposed FC + BESS pad. Tie-in feasibility memo within 5 business days.
Book site walkOne-page. Standard B2B. Unlocks: OEM bids, EPC partner introductions, peer CA WWTP biogas references with operational data, LTSA template. Triggers Phase 2 entry.
Download NDABCal drafts LOI for NapaSan FD&O review. §6417 Direct Pay eligibility memo + bond counsel concurrence. Board briefing material aligned to CIP 25708 capital schedule.
Request LOIMutual NDA + non-circumvention unlocks OEM identities, peer-deployment data, and LTSA templates. LOI puts NapaSan into the §48E construction-start window.
One-page. Mutual two-year term. Covers OEM identities, EPC partner introductions, peer-customer operational data, LTSA pricing comparables, RES-BCT routing logic. Designed for one-pass legal review.
Request NDA template (PDF)Letter of Intent within 5 business days of site walk. Preliminary economics, governance approval pathway, BCal developer-fee structure, capital-plan timing aligned to CIP 25708, §6417 Direct Pay flow.
Request LOIOn-site at Soscol WRF. Central electrical room, CIP 25708 design package walk-through, biogas piping, proposed FC + BESS pad, MCC tie-in points. Tie-in feasibility memo within 5 business days of the walk.
All projections on this page are preliminary and subject to material revision. Numbers shown are derived from publicly-available data (NapaSan ACFR, board packets, CIP 10-yr plan, FY budget, MCE / CWEA disclosures, PG&E tariffs, CARB / BAAQMD filings, public OEM datasheets, industry benchmarks) and BCal modeling assumptions disclosed under Block A/B/C/D of the parallel PDF term sheet. Every dollar figure, MW size, $/kWh rate, GHG ton, NOx number, and timeline date will change based on (a) the free Phase-1 14-day memo run against NapaSan-confirmed data, (b) firm vendor quotes received in Phase 2 bake-off, (c) site walk findings, (d) CPRA-confirmed utility + digester gas data, (e) BAAQMD + PG&E Rule 21(M) interconnect-study outcomes, (f) NapaSan Board procurement decisions, and (g) federal / state policy revisions to §48E, §6417, SGIP, RES-BCT, and BAAQMD rules. Specific OEM identities, EPC partner names, peer-customer references, and firm pricing terms are intentionally not disclosed on this page — they sit behind a one-page mutual NDA + non-circumvention at Phase 2 entry. BCal does not provide tax advice. NapaSan should consult its own tax counsel regarding §6417 Direct Pay and §48E ITC eligibility. This page is not an offer. Contact info@bcalenergy.com to initiate.