Solar and Alternative Energy Products Industry Terminology

We designed an AC-coupled solar+storage retrofit to avoid touching the existing PV wiring; The microgrid uses AC-coupled batteries to support black start; AC coupling simplified interconnection because the storage has its own certified inverter.

A vineyard installed agrivoltaics to shade vines and produce power; The agrivoltaics design elevated modules to allow tractor access; Grants favor agrivoltaics that maintain crop yields.

For the northern hemisphere, due south is 180 degrees azimuth; We optimized array azimuth at 210 degrees to capture late-afternoon TOU pricing; Tracker backtracking logic uses each row’s azimuth.

BOS costs include racking, wiring, combiner boxes, and labor; The BOS vendor standardized on 1500Vdc to cut copper costs; BOS optimization reduced LCOE by 4%.

The lender questioned the bankability of the new perovskite module; We selected a Tier 1, bankable inverter platform; Bankability drove our choice of a long-warranty tracker supplier.

The 10‑MWh BESS provides peak shaving and frequency response; The BESS includes a fire suppression system per NFPA 855; We modeled the BESS degradation over 10 years at 80% RTE.

Bifacial panels gained 8% yield on white gravel due to high albedo; The design used 1.2m ground clearance to boost bifacial gain; We calibrated PVsyst with site albedo to estimate bifacial yield.

The plant’s capacity factor is 26% based on annual metered kWh; Trackers improved capacity factor relative to fixed-tilt; Capacity factor assumptions feed directly into LCOE.

Our EPC bid priced CAPEX at $0.95/Wdc; Shifting to monopiles lowered CAPEX; Investors compared CAPEX across tracker and fixed-tilt options.

CAISO signaled midday curtailment due to oversupply; We modeled 5% curtailment in the P50 energy forecast; Storage reduces curtailment by shifting energy to peak hours.

The pro forma assumes 0.5% annual module degradation; Higher temperatures accelerated degradation in the desert site; Warranty covers degradation not exceeding 2% in year one, then 0.4% per year.

The BESS discharges to reduce the monthly demand peak; Analytics identified a 15‑minute window for demand charge management; We combined HVAC controls with storage to shave peaks.

We limit DoD to 80% to extend cycle life; The warranty specifies 6,000 cycles at 70% DoD; Daily DoD is shallower on weekends due to lower loads.

The utility uses a DERMS to dispatch VPPs for peak relief; DERMS enforces feeder export limits on rooftop PV; We integrated DERMS signals with the site’s EMS.

High DNI makes CSP viable; Trackers use DNI-driven yield models; We chose bifacial fixed-tilt due to low site DNI.

We selected a single EPC under a turnkey contract; The EPC guaranteed substantial completion by Q4; EPC self-performed pile driving to control schedule.

The site’s specific yield is 1,700 kWh/kWp-year; Bifacial gain increased energy yield by 7%; Our P50 yield excludes curtailment, while P90 includes it.

Germany’s FiT sparked early PV adoption; The FiT rate steps down for later tranches; FiT contracts require metering on the utility side of the meter.

FPV reduced reservoir evaporation and improved output; Anchoring design accounts for water level changes; We evaluated corrosion risk for FPV on brackish water.

GHI drives fixed-tilt PV yield modeling; We sourced TMY data to estimate site GHI; Cloud cover lowered GHI by 8% year over year.

Interconnection requires IEEE 1547 ride-through settings; The inverter’s grid support functions comply with IEEE 1547-2018; Our utility references IEEE 1547 in its standards manual.

Our project waited 24 months in the PJM queue; The cluster study advanced several queue positions; Posting security is required to hold a queue spot.

We elected the 30% ITC with a domestic content adder; Tax equity monetizes the ITC at financial close; The project instead opted for the PTC due to high capacity factor.

Commissioning included IV curve tracing to detect mismatch; Soiling distorted the IV curve, reducing fill factor; The IV curve confirmed a string outage.

Our tracker design lowered LCOE by 6%; Sensitivity shows WACC dominates LCOE; Adding storage changes the effective LCOE of delivered energy.

Higher cycle life reduced LCOS materially; Round-trip efficiency and CAPEX drive LCOS; LCOS improves with revenue stacking (arbitrage plus capacity).

We modeled 5‑year MACRS depreciation for PV; Bonus depreciation improved tax shield value; The sponsor’s tax appetite dictates MACRS utilization.

String-level MPPT improves partial shading tolerance; The charge controller’s MPPT boosts PV-to-battery harvest; We compared 2‑MPPT vs 4‑MPPT inverters for mismatch losses.

The plant’s nameplate is 150 MWdc and 120 MWac; Interconnection limits AC nameplate export; Incentives cap awards at 5 MW nameplate.

Article 690.12 mandates rapid shutdown for rooftops; Our design follows 690.31 for PV wiring methods; The AHJ required labeling per NEC 690.

Under NEM 3.0, export credits align with avoided cost; We sized the system to offset 90% of annual usage under NEM; Policy changes shifted NEM economics toward storage.

Using a 7% WACC, the PPA yields positive NPV; Sensitivity shows NPV most affected by curtailment; The sponsor’s hurdle rate dictates acceptable NPV.

O&M includes vegetation control and inverter service; The O&M agreement guarantees response times; Predictive O&M uses SCADA data to reduce truck rolls.

PERC cells improved module efficiency by ~1% absolute; We mitigated LeTID risk in PERC modules with process controls; The tender specified PERC or better cell tech.

High system voltage accelerated PID on the test string; Anti-PID devices reduced leakage currents; The module spec lists PID resistance per IEC testing.

A 20‑year fixed-price PPA underpins financing; The corporate PPA is a virtual (financial) swap; The offtaker’s credit rating drives PPA bankability.

We elected the PTC due to high capacity factor; The PTC provides inflation-adjusted $ per MWh for 10 years; Modeling compares ITC vs PTC outcomes.

The state RPS target is 60% by 2030; SREC markets help utilities meet RPS obligations; RPS carve-outs favor distributed solar.

Our Li-ion RTE is 88% at the tested C-rate; RTE drops at low temperatures; Higher RTE improves LCOS.

SCADA alerts flagged inverter trips; Operators curtail output via SCADA setpoints; We trended SCADA data to diagnose soiling losses.

Trackers increased yield by ~15% vs fixed-tilt; Backtracking minimized row-to-row shading; Tracker availability is part of the O&M KPI set.

The EMS maintains SoC between 20% and 90%; Low SoC reserves are held for resource adequacy; We scheduled charging to start at 40% SoC before peak.

A spring dust storm caused 5% soiling losses; The cleaning plan reduced soiling to under 2%; We installed soiling sensors to calibrate the model.

We forward-sold SRECs to enhance project revenue; SREC prices fell after supply increased; The project registered its SRECs with the state tracker.

We chose string inverters for better MPPT granularity; Centralized O&M favored 250‑kW string inverters; The design balanced string inverter count against AC losses.

A partnership flip structure monetized ITC and MACRS; Tax equity availability set the COD schedule; The sponsor lined up a tax equity investor before NTP.

We shifted discharge to high TOU periods to maximize value; TOU changes reduced midday export credits; The PPA is indexed to the utility’s TOU schedule.

The inverter is certified to UL 1741 SA for smart functions; CA Rule 21 requires UL 1741 SA compliance; We verified ride-through per UL 1741 SA test profiles.

The aggregator’s VPP earns capacity payments; Homes in the VPP provide peak shaving; DERMS dispatches the VPP during critical peaks.

Lowering WACC by 100 bps cut LCOE by 7%; WACC assumptions drive NPV outcomes; Tax equity impacts the blended WACC.