Root element for PvPlanner calculate requestOptionally, terrain or horizon data can be specified, otherwise default values are fetched for given latlngoptional, if 'true' mounting angles are not taken into account during calculation, but the optimized angles which are also returned in resultRoot element for PvPlanner calculate responsePV system summary text, example: PV system: 1.0 kWp, crystalline silicon, fixed free, azim. 180° (south), inclination 30°Global horizontal irradiation and air temperature - climate referenceMonthly sum of global irradiation [kWh/m2]Daily sum of global irradiation [kWh/m2]Daily sum of diffuse irradiation [kWh/m2]Daily (diurnal) air temperature [°C]Minimum air temperature [°C]Maximum air temperature [°C]Interannual variability of annual global horizontal irradiation [%]Global in-plane irradiationMonthly sum of global irradiation [kWh/m2]Daily sum of global irradiation [kWh/m2]Daily sum of diffuse irradiation [kWh/m2]Daily sum of reflected irradiation [kWh/m2]Losses of global irradiation by terrain shading [%]PV electricity production in the start-upMonthly sum of specific electricity production [kWh/kWp]Daily sum of specific electricity production [kWh/kWp]Monthly sum of total electricity production [kWh]Percentual share of monthly electricity production [%]Performance ratio [%]
System losses and performance ratio
Energy conversion steps and losses:
1. Initial production at Standard Test Conditions (STC) is assumed,
2. Reduction of global in-plane irradiation due to obstruction of terrain horizon and PV modules,
3. Proportion of global irradiation that is reflected by surface of PV modules (typically glass),
4. Losses in PV modules due to conversion of solar radiation to DC electricity; deviation of module efficiency from STC,
5. DC losses: this step assumes integrated effect of mismatch between PV modules, heat losses in interconnections and cables, losses due to dirt, snow, icing and soiling, and self-shading of PV modules,
6. This step considers euro efficiency to approximate average losses in the inverter,
7. Losses in AC section and transformer (where applicable) depend on the system architecture,
8. Availability parameter assumes losses due to downtime caused by maintenance or failures.
Losses at steps 2 to 4 are numerically modeled by pvPlanner. Losses at steps 5 to 8 are to be assessed by a user.
Global in-plane irradiation (input)Global irradiation reduced by terrain shadingGlobal irradiation reduced by reflectivityConversion to DC in the modulesOther DC lossesInverters (DC/AC conversion)Transformer and AC cabling lossesReduced availabilityTotal system performanceEnergy output [kWh/kWp]Energy loss [kWh/kWp], optionalEnergy loss [%], optionalPerformance ratio [partial %]Performance ratio [cumul. %]Average yearly sum of global irradiation for different types of surfaceHorizontal surfaceOptimally inclined surfaceSurface with 2-axis trackingSelected system surface mountingAverage yearly sum of global irradiation [kWh/m2]Relative comparison to optimally inclined [%]Optimum inclination angles for different mounting typesSolar radiation reference and inplane values, strategy comparison and optimum angles includesPhotovoltaic calculation results
Date period abstract type, implementing types are DatePeriodExpr and DatePeriodConstrequired are any two of attributes, to determine exact date periodValues for all 12 months (January-December) separated by space, example: 85.6 85.1 84.1 81.2 79.1 78.1 77.5 77.8 80.0 81.9 83.4 84.5Yearly summary of average of monthly valuessigned percent value bounded to maximum 100%To determine DateWithTimeZone JAXB generation, at XML level same as xs:dateTime Zone definition according to Greenwich Mean Time, valid pattern: GMT[+-][number of hours]

Pair of double values separated by colon character ':'

Date expression format:
TODAY - today's date
DATE:2012-12-31 - date constant in format yyyy-MM-dd
META - date fetched by metadata service
MONTH:-5:LEFT - today - 5 months, aligned to beginning of month
YEAR:0:RIGHT - today, aligned to end of current year
begin date of the date rangeend date of the date rangebegin date of the date rangeend date of the date range
Latitude coordinate in decimal format [-90,90]Longitude coordinate in decimal format [-180,180]azimuth direction in degreesinclination angle in degreesAddress and country data of specified locationISO2 country codeTerrain data corresponding to LatLng locationAltitude of surface at specified location in metersSlope inclination at specified location; 0 horizontal, 90 verticalSlope orientation at specified location; 0 for North, 180 for South, clockwiseSolarGIS horizon format: [azimuth degrees:0-360]:[horizon degrees:0-90] ...multiple values... Example: 0:5 7.5:3 15:7 22.5:0Latitude longitude coordinates
PV system configurationInstalled PV system power [kWp]lower limit is 0 kWpPV system startup date for degradation calculationPV system availability [%]Losses of system componentsAnnual value of the percentual loss [%]; Typically 1 – 10% loss of power12 monthly values of percentual losses [%]; Typically 1 – 10% loss of powerOmic losses pre-calculated by user [%]; Typically 0.7 – 1.5 % loss of powerGiven by manufacturer (power tolerance dependent) [%]; Typically 0.5 – 1.0 % loss of powerAC losses - transformer [%]AC losses - cables [%]Syntethic DC losses - aggregated PollutionSnow, DCCables and DCMismatch losses [%]Transformer and AC cabling losses [%]annual degradation of pv modules [%]annual degradation for the first year [%]empirical coeff, dimensionless (typical value 0.12)low limit tolerance of nominal power at STC [%]
high limit tolerance of nominal power at STC [%]
Nominal Operating Cell Temperature (NOCT) [°C]Thermal coeffiecient of Open circuit voltage, in % per degree Celsius [%/°C]Thermal coefficient of Short circuit current, in % per degree Celsius [%/°C]Thermal coefficient of nominal power at STC, in % per degree Celsius [%/°C]required if installedPower is not defined and vice versaPV module type enumerationcrystalline silicon (c-Si)amorphous silicon (a-Si)cadmium telluride (CdTe)copper indium selenide (CIS)number of modules[W]minimum power when inverter starts to work [kW]maximum power when inverted limits the AC output [kW][kW]number of invertersinverter interconnection enumerationInverter efficiency model abstract typeConstant inverter efficiency, typically 70 - 100 [%]Efficiency curve defined by data pairsPV systems topology configurationif unspecified, default value is PROPORTIONAL (CSI,ASI,CDTE) or UNPROPORTIONAL1 (CSI)Shading angle is the lowest sun elevation angle above the horizon plane which doesn't cause mutual shading between rows of PV modules[m][m]Optimization category into which field topology of PV system belongs, qualitative and empirical rankingapplicable for a-Si, CdTe and CIS (thin film technologies), the loss of generated electricity is proportional to the size of module area in shadeapplicable for c-Si, modules are landscape oriented with proper layout optimizationapplicable for c-Si, modules are landscape oriented with intermediate layout optimizationapplicable for c-Si, modules are portrait oriented with poor layout optimization, bottom cells in shade will shut the whole row of modules downPV system mounting abstract typeInclined surface tilt; 0 horizontal, 90 verticalInclined surface orientation; 0 for North, 180 for South, clockwise