Solar & Alternative Energy Products Industry Terminology

We're opting for an AC-coupled BESS so we can retrofit storage without touching the PV DC strings.|AC coupling adds an extra conversion step, so we modeled a 1–3% round-trip efficiency penalty versus DC-coupled.|The microgrid will use AC-coupled solar, wind, and storage to simplify islanding and coordination.

Our base case uses 5-year MACRS with bonus depreciation to enhance after-tax cash flows.|Without MACRS, the tax equity yield would fall below target.|We modeled MACRS timing to align with the PPA COD for optimal tax benefits.

The BESS will bid into frequency regulation and spinning reserves for ancillary revenue.|We sized the inverter to provide reactive power support as an ancillary service.|The project’s revenue stack includes energy arbitrage plus ancillary services in CAISO.

By standardizing skids, we cut BOS costs by 8%.|As module prices fall, BOS becomes a larger share of total CapEx.|BOS scope includes racking, cabling, combiner boxes, trenching, and labor.

The 100 MW/400 MWh BESS will provide peak shaving and capacity.|We specified a 2-hour BESS coupled with PV for TOU arbitrage.|BESS O&M includes HVAC maintenance, firmware updates, and capacity testing.

With high-albedo gravel, we expect a 6–10% bifacial gain.|Tracker height and row spacing were optimized for bifacial performance.|The EPC will conduct a bifaciality factor test on delivered modules.

The site’s expected capacity factor is 27% with single-axis trackers.|Increasing ILR can raise the effective capacity factor.|We benchmarked capacity factors across ISOs to compare resource quality.

Module prices dropped, but interconnection CapEx increased due to upgrades.|Our CapEx includes owner’s costs and contingency at 5%.|We split CapEx into module, BOS, EPC margin, and interconnection buckets.

The project will be a 5 MW community solar farm with residential subscribers.|We’ll use consolidated billing to simplify community solar collections.|Churn assumptions are critical in the community solar revenue model.

Our EMS will curtail HVAC load to participate in utility DR events.|The battery pre-charges so we can respond to DR calls without impacting operations.|DR revenue helps offset demand charges in summer months.

We assumed 0.5% annual module degradation for the P50 case.|Year 1 light-induced degradation was incorporated in the energy model.|Performance warranty covers degradation beyond the guaranteed curve.

The EPBT for this PV technology is under two years in high-irradiance regions.|Thin-film modules show favorable EPBT in some climates.|EPBT is a key metric in lifecycle sustainability reporting.

We’ll issue an EPC RFP with a turnkey scope and performance guarantees.|The EPC will manage soil remediation and pile testing prior to construction.|EPC wrap includes schedule liquidated damages and availability guarantees.

Under the FiT, all exported kWh earn a fixed price for 20 years.|The FiT rate degresses quarterly to track cost declines.|We compared FiT eligibility versus self-consumption economics.

This is an FTM solar-plus-storage asset selling into the wholesale market.|FTM projects face interconnection queues and deliver ancillary services.|We differentiated FTM from behind-the-meter economics in our analysis.

The electrolyzer will run on curtailment to produce green hydrogen.|We’re targeting an LCOH below $3/kg with high-capacity-factor renewables.|The offtake MOU covers green H2 for industrial heat displacement.

Rooftop PV hit grid parity under current TOU rates.|We modeled parity versus wholesale prices for the utility-scale plant.|Battery adders can accelerate parity in high-peak markets.

The offshore wind export cable uses HVDC to reduce losses.|HVDC enables long-distance transmission from high-resource regions.|Converter stations add CapEx but lower line losses over distance.

We chose hybrid inverters to manage PV and battery through one device.|Hybrid inverters enable backup power during outages in island mode.|The UL 1741-listed hybrid inverter supports advanced grid functions.

With a 1.35 ILR, clipping increases slightly but boosts annual kWh.|Higher ILR improves morning/evening output and capacity value.|We tested ILR sensitivity from 1.2 to 1.5 in the energy model.

The project claims a 30% ITC with applicable adders.|Transferability lets us monetize the ITC without a traditional tax equity investor.|We modeled ITC step-up and recapture risk in the financing case.

The module J-box houses bypass diodes and the cable leads.|Inspect J-box potting quality to avoid moisture ingress.|A failed J-box can trigger hot spots and string outages.

The 500 kWp rooftop system is sized to offset 60% of annual load.|Module nameplate at STC is 550 Wp, so the array totals 3,300 kWp.|Design ILR uses DC kWp versus AC kW inverter capacity.

Our LCOE estimate is $32/MWh for the solar farm.|Lower WACC and higher ILR both help reduce LCOE.|We compared LCOE to PPA strike prices and merchant curves.

We selected LFP cells for safety and cycle life at the expense of energy density.|LFP thermal runaway risk is lower than NMC in our hazard analysis.|The LFP pack warranty guarantees 70% capacity at year 10.

The inverter’s MPPT windows must match the string voltage at temperature extremes.|MLPE can enable module-level MPPT under partial shading.|Efficient MPPT improves yield, especially on variable irradiance days.

We used optimizers to meet rapid shutdown and boost yield on complex roofs.|MLPE increases CapEx but can improve energy harvest and monitoring granularity.|Microinverters are a form of MLPE with AC output at each module.

Under NEM, exported kWh offset imports at retail rates.|NEM 3.0 shifted to net billing with time-varying export credits.|Storage improves economics as NEM credits decline.

The utility is procuring NWA solutions to defer a substation upgrade.|A portfolio of PV, storage, and DR can serve as an NWA.|We quantified locational value to compete in the NWA solicitation.

The Fortune 500 offtaker signed a 15-year virtual PPA.|We evaluated offtaker credit risk and termination rights.|Municipal offtakers may require specific contract forms.

Proactive O&M reduced truck rolls and inverter downtime.|Annual O&M includes vegetation management and IV-curve tracing.|The O&M contract has availability guarantees and response SLAs.

The PV array uses monocrystalline PERC modules on trackers.|PV output is forecast using TMY data and loss factors.|We compared PV to solar thermal for process heat needs.

The offtaker agreed to a 20-year fixed-price PPA with a 1% escalator.|We considered a proxy generation PPA to handle curtailment risk.|PPA codifies delivery terms, pricing, and performance guarantees.

We compared ITC versus PTC election for the solar project under current policy.|Higher capacity factor favored the PTC in our case.|Revenue modeling includes PTC inflation adjustments where applicable.

The project seeks QF certification to sell under PURPA avoided cost rates.|We filed the FERC Form 556 to register as a QF.|QF status can improve interconnection priority in some cases.

Our QA/QC plan includes factory witness tests and receipt inspections.|We perform EL imaging to detect cell cracks for QC.|QA/QC reduces early-life failures and warranty claims.

Inverters provide reactive power to maintain feeder voltage.|The interconnection agreement requires a ±0.95 power factor range.|We sized inverters for reactive capability during peak solar output.

We’ll unbundle RECs and sell them into the voluntary market.|The PPA is energy-only; RECs are retained by the offtaker.|Tracking registries verify REC creation and retirement.

The state’s RPS hits 60% by 2030, driving utility procurement.|SREC multipliers help meet solar carve-outs within the RPS.|We track RPS eligibility to value project RECs.

SATs increased yield by ~15% versus fixed-tilt at this latitude.|Tracker controls include backtracking to reduce row-to-row shading.|We analyzed O&M impacts of SAT gearboxes and motors.

The solar-plus-storage plant will time-shift energy into evening peaks.|Co-located solar-plus-storage optimizes interconnection capacity.|Revenue stacking includes energy, capacity, and ancillary services.

The project sells SRECs into a state solar carve-out market.|SREC prices affect PPA negotiation in compliance states.|We modeled SREC strip sales to de-risk revenue.

We’re pursuing a partnership flip structure with a tax equity investor.|Transferability offers an alternative to traditional tax equity.|Tax equity diligence includes ITC/PTC qualification and MACRS.

Storage charges off-peak and discharges during high TOU periods.|We sized the battery to hedge the evening TOU super-peak.|NEM reforms shifted export credits to TOU schedules.

The inverter is certified to UL 1741 SB for IEEE 1547-2018 functions.|Rule 21 requires UL 1741 SA capabilities for grid support.|Certification covers ride-through and voltage/reactive power modes.

Utility-scale solar competes at sub-$30/MWh in some regions.|Interconnection and transmission constraints dominate utility-scale timelines.|We’re bidding utility-scale solar into the ISO capacity auction.

The VOS tariff compensates exports based on avoided costs.|We calculated VOS components: energy, capacity, T&D, and environmental.|VOS may replace net metering in the proposed policy.

The VPP aggregates home batteries to bid into frequency regulation.|Enrollment in the VPP provides bill credits during DR events.|We’re integrating PV inverters and EV chargers into the VPP platform.

Lowering WACC by 100 bps reduces LCOE materially.|Our WACC assumption reflects tax equity, debt, and sponsor equity costs.|Sensitivity shows WACC dominates valuation uncertainty.

The offtaker pays a wheeling charge to move energy across a neighboring utility’s lines.|Wheeling costs affect the economics of remote PPA delivery.|We negotiated reduced wheeling tariffs for the corporate VPP.