Electric Objects

This section presents an in-depth description of all objects available in SAInt that are available to develop an electric network model. SAInt is written with an object-oriented programming language, and thus the presentation of available objects is approached with the object hierarchy. Figure 1 shows the hierarchy of the parent-child relationships of all electric objects. Table 1 gives concise descriptions of all electric objects.

The top-level base object in an electric network model is the "Electric Network" object ENET. An electric network may contain many other base objects, such as electric demands EDEM or electric lines LI. An electric branch EBR is the parent object, while an electric line LI or an electric transformer TRF are the child objects; this means that both the electric line and electric transformer share some base properties of the electric branch. Objects that are not a base class for any other objects can only be children. For instance, the electric line object LI is not a base class for any other objects, and thus it can only a child. See the schematic below for a visual representation of the complete hierarchical object structure for the electric network model in SAInt.

Figure 1. Relationship between objects in electric network. A child object is indicated by the head of a pointed arrow, while a parent is by the tail. Please, open the image in another window of your Internet browser to enlarge it.

Table 1. Icons and descriptions of object types in electric network model.
ObjType	Display Name	Description
`ENET`	Electric Network	Models the characteristics and interactions of facilities and/or components of an electric network or market. Serves as a container for all objects in the electric network
`ESUB`	Electric Sub	Models a subset of nodes, branches, and externals of an electric network. An electric sub is branch-oriented, i.e., only electric branches can be assigned to an electric sub, and every electric branch belongs to only one electric sub
`EZN`	Electric Zone	Models a subset of nodes, branches, and externals of an electric network. An electric zone is node-oriented, i.e., only electric nodes can be assigned to an electric zone, and every electric node belongs to only one electric zone
`EGRP`	Electric Group	Models a subset of different objects in an electric network. Except for the electric network, subs, and zones, any electric object can be added to an electric group. In contrast to electric subs and zones, electric groups do not follow any specific assignment rules. Thus, an electric object can be part of multiple electric groups
`ENO`	Electric Node	Models a physical or virtual location in the electric network where electric power can be injected or extracted through externals (electric demand, generators, storages, etc.)
`EBR`	Electric Branch	Base object type for all electric branches. Models a directed connection between two electric nodes
`LI`	Electric Line	Models the transport of electric power between two distant locations
`TRF`	Electric Transformer	Models a local increase (step-up) or decrease (step-down) of voltage between areas of different voltage levels in the electric network
`EXT`	Electric External	Base object type for all electric externals. An electric external is a directed connection to a single node that allows the extraction and injection of electric power
`EDEM`	Electric Demand	Models the extraction (consumption) of electric power at a node
`XGEN`	Generic Generator	Models a generator or an external network injecting electric power into the electric network
`FGEN`	Fuel Generator	Models the injection of electric power by a fuel generator that generates electricity by converting chemical energy stored in a fuel first into mechanical energy and then into electrical energy. A fuel generator requires a fuel object (oil, gas, coal, nuclear, etc.) for operation
`HGEN`	Hydro Generator	Models the injection of electric power from a hydro generator. The amount of electricity produced depends on the volumetric flow rate (TURB) driving the hydro turbines and a coefficient describing the active power generation per volumetric rate (PCOEFF). A hydro generator is always connected to a hydro power plant
`WIND`	Wind Generator	Models the injection of electric power from a wind generator. The electric power generation profile for a wind generator can be generated from wind weather resource data and the characteristics of the wind generator (wind turbine power curve, hub height, etc.)
`PV`	Solar Generator	Models the injection of electric power from a solar generator. The electric power generation profile for a solar generator can be generated from solar weather resource data and the characteristics of the solar generator (PanelType, Tilt Angle, etc.)
`ESTR`	Electric Storage	Models the storage of electric energy in electric storage systems, such as battery, flywheel, or compressed air
`SHT`	Electric Shunt	Models a shunt reactor or capacitor. Shunt reactors are placed locally to control the over-voltages at electric nodes under light load conditions (consume reactive power to reduce the nodal voltage), while shunt capacitors are used to boost the voltage in a stressed system (supply reactive power to increase the nodal voltage)
`FUEL`	Fuel	Models the consumption and emission of the fuel used by one or more fuel generators
`HYDP`	Hydro Plant	Models a hydro power plant consisting of one or more hydro generators. Water flows into the hydro power plant either from inflow (rain, etc.), water turbinated by another hydro power plant, or spillage from a hydro power plant. Hydro power plants have a maximum and minimum reservoir volume; the difference determines the volume that can be turbinated through a hydro generator. The hydro power plant has three outflow types, namely, outflow, turbination, and spilling
`ASVC`	Ancillary Service	Models the ability of generators and demands to provide reserve capacity (upward or downward reserve) to the electric network in case of an unexpected contingency
`ASVCX`	Ancillary Service External	Models the facilities contributing to an ancillary service
`ECNSTR`	Electric Constraint	Models a user-defined linear equality or inequality constraint describing relations between the variables of different electric objects
`EVAR`	Electric Variable	Models a variable of an electric object and its corresponding coefficient utilized in a user-defined constraint

1. Electric network (ENET)

An electric network object is the top parent object in any model of an electric system in SAInt (Figure 1). An electric network object is modeled as a directed graph consisting of sets of electric nodes, branches, and externals; branches connect two nodes, while externals are connected to only a single node. An electric network contains all of the geometric, topological, and relational information required to create the graph, as well as all network child objects and their static/physical properties that do not change during the execution of a simulation (e.g., the length of a transmission line).

The "nodes" of an electric network identify junctions in the network graph where branches and externals connect. among the network branches and the connection point for externals.

The "branches" of an electric network establish the connectivity of the network and can passively (e.g., electric lines) or actively (e.g., tap changing transformers) modify the state of the electricity that flows across them. Branches of an electric network are "lines" and "transformers".

The "externals" of an electric network represent objects supplying or withdrawing electrical power from the system. Externals of an electric network are generators, "demands", "shunts, and "storages. SAInt models a variety of different types of generators, such as "wind generators", "solar generators, "generic generators", "fuel generators, and "hydro generators",

An electric network can also contain other electric-specific objects such as "fuels", "ancillary services", "ancillary service externals", "electric variables", "electric constraints", and "hydropower plants".

Summaries for the properties and events of ENET.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-event-value properties of ENET.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ENET, which are applicable in ACPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ENET, which are applicable in UACPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ENET, which are applicable in DCUCOPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ENET, which are applicable in ACOPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of ENET.
Extension	Description	UnitType
PCM	Active power compensation mode used in power flow simulations	NO
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPGSHDW	Maximum shadow price for active power generation	NRGPRC
MAXPGSHDWAT	Maximum shadow price for active power generation	NO
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
MAXQGSHDW	Maximum shadow price for reactive power generation	NRGPRC
MAXQGSHDWAT	Maximum shadow price for reactive power generation	NO
MAXQSHDW	Maximum shadow price for reactive power	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
MAXVSHDW	Maximum shadow price for voltage magnitude	VPRC
MAXVSHDWAT	Maximum shadow price for active power generation	NO
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
TOTCOSTRATE	Total cost for operating generators and storages per time. Calculated in the network, sub, zone or group as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
QLC	Total line charging	QPOW
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
COST	Total operating costs	PRCDOT
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

Summary for the derived-result properties of ENET, which are applicable in ACPF.
Extension	Description	UnitType
PCM	Active power compensation mode used in power flow simulations	NO
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
QLC	Total line charging	QPOW
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG

Summary for the derived-result properties of ENET, which are applicable in UACPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
QLC	Total line charging	QPOW
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG

Summary for the derived-result properties of ENET, which are applicable in DCUCOPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
VAMIN	Minimum voltage angle	ANGLE
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
TOTCOSTRATE	Total cost for operating generators and storages per time. Calculated in the network, sub, zone or group as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

Summary for the derived-result properties of ENET, which are applicable in ACOPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPGSHDW	Maximum shadow price for active power generation	NRGPRC
MAXPGSHDWAT	Maximum shadow price for active power generation	NO
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
MAXQGSHDW	Maximum shadow price for reactive power generation	NRGPRC
MAXQGSHDWAT	Maximum shadow price for reactive power generation	NO
MAXQSHDW	Maximum shadow price for reactive power	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
MAXVSHDW	Maximum shadow price for voltage magnitude	VPRC
MAXVSHDWAT	Maximum shadow price for active power generation	NO
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
QLC	Total line charging	QPOW
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
COST	Total operating costs	PRCDOT
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of ENET.
Extension	Description	UnitType
BaseS	Nominal apparent power for conversion to network wide per unit system	SPOW
BaseF	Base frequency for the entire network	FRQ
CRSType	Network coordinate reference system for the node locations
Info	Information related to the network model. Any character, including non-alphanumeric, is allowed

Summary for the net-input properties of ENET, which are applicable in ACPF.
Extension	Description	UnitType
BaseS	Nominal apparent power for conversion to network wide per unit system	SPOW
BaseF	Base frequency for the entire network	FRQ
CRSType	Network coordinate reference system for the node locations
Info	Information related to the network model. Any character, including non-alphanumeric, is allowed

Summary for the net-input properties of ENET, which are applicable in UACPF.
Extension	Description	UnitType
BaseS	Nominal apparent power for conversion to network wide per unit system	SPOW
BaseF	Base frequency for the entire network	FRQ
CRSType	Network coordinate reference system for the node locations
Info	Information related to the network model. Any character, including non-alphanumeric, is allowed

Summary for the net-input properties of ENET, which are applicable in DCUCOPF.
Extension	Description	UnitType
BaseS	Nominal apparent power for conversion to network wide per unit system	SPOW
BaseF	Base frequency for the entire network	FRQ
CRSType	Network coordinate reference system for the node locations
Info	Information related to the network model. Any character, including non-alphanumeric, is allowed

Summary for the net-input properties of ENET, which are applicable in ACOPF.
Extension	Description	UnitType
BaseS	Nominal apparent power for conversion to network wide per unit system	SPOW
BaseF	Base frequency for the entire network	FRQ
CRSType	Network coordinate reference system for the node locations
Info	Information related to the network model. Any character, including non-alphanumeric, is allowed

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of ENET.
Extension	Description	UnitType
Name	Name of the network model. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter.
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ENET, which are applicable in ACPF.
Extension	Description	UnitType
Name	Name of the network model. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter.
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ENET, which are applicable in UACPF.
Extension	Description	UnitType
Name	Name of the network model. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter.
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ENET, which are applicable in DCUCOPF.
Extension	Description	UnitType
Name	Name of the network model. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter.
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ENET, which are applicable in ACOPF.
Extension	Description	UnitType
Name	Name of the network model. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter.
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
DCUCOPF
ACOPF

Summary for the events of ENET.
Parameter	Type	Description	UnitType
DECOUPLEHYDRO	IniSetting	Disregard coupling between hydro generators and hydro plants.	NO
INCLUDELOSS	IniSetting	Include line losses.	NO
NOASVC	IniSetting	Disregard ancillary services.	NO
NOCONSTR	IniSetting	Disregard all user defined constraints.	NO
NODROP	IniSetting	Disregard voltage angle drop equation.	NO
NOLASTHOR	IniSetting	No last Horizon.	NO
NOLINECAP	IniSetting	Disregard line constraints.	NO
PRIOR	IniSetting	Turn on active power compensation mode proiritization.	NO
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
REVON	IniSetting	Differentiate between forward and reverse flow through branches.	NO
SPILLPRC	PenaltyPrice	Penalty price for spilled flow. Minimum: 0.	VOLPRC

Summary for the events of ENET, which are applicable in ACPF.
Parameter	Type	Description	UnitType
PRIOR	IniSetting	Turn on active power compensation mode proiritization.	NO

Summary for the events of ENET, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
DECOUPLEHYDRO	IniSetting	Disregard coupling between hydro generators and hydro plants.	NO
INCLUDELOSS	IniSetting	Include line losses.	NO
NOASVC	IniSetting	Disregard ancillary services.	NO
NOCONSTR	IniSetting	Disregard all user defined constraints.	NO
NODROP	IniSetting	Disregard voltage angle drop equation.	NO
NOLASTHOR	IniSetting	No last Horizon.	NO
NOLINECAP	IniSetting	Disregard line constraints.	NO
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
REVON	IniSetting	Differentiate between forward and reverse flow through branches.	NO
SPILLPRC	PenaltyPrice	Penalty price for spilled flow. Minimum: 0.	VOLPRC

Summary for the events of ENET, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC

By default, the event NOLASTHOR is set to False. If the sum of the TimeHorizon and TimeLookAhead of the last consecutive run exceeds the EndTime, the fraction of the TimeLookAhead that extends beyond the EndTime is truncated. For example, with a TimeWindow of 6 days, 2 days TimeHorizon, and 3 days TimeLookAhead, SAInt will execute 3 consecutive runs, where in the first run, the last TimeLookAhead is of 3 days, in the second run of 2 days, and in the last run is completely truncated rather than being of 2 days. In this example, if the event NOLASTHOR is set to True (not recommended), the last TimeLookAhead is completely neglected.

2. Electric network container

The child objects of a network can be grouped into the following subsets, also referred to as "containers": sub, zone, and group. These arrangements can be used to define relevant information for a network, or they can simply be used to conveniently aggregate outputs of a scenario.

2.1. Electric sub (ESUB)

A sub (also referred to as sub-network or sub-system) is a subset of nodes, branches, and externals of a network. A sub is branch-oriented, i.e., only branches can be assigned to a sub, and every branch belongs to only one sub. The FromNode and ToNode of a branch, as well as the externals connected to these two nodes, are implicitly added to the sub. Thus, nodes connecting branches of different subs and the externals connected to these nodes are always included in multiple subs. But all properties of a sub are determined by the branches belonging to it.

Intro
derived-event-value
derived-result
net-input
net-read-only

Summaries for the properties and events of ESUB.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-event-value properties of ESUB.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ESUB, which are applicable in ACPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ESUB, which are applicable in UACPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ESUB, which are applicable in DCUCOPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ESUB, which are applicable in ACOPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of ESUB.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPGSHDW	Maximum shadow price for active power generation	NRGPRC
MAXPGSHDWAT	Maximum shadow price for active power generation	NO
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
MAXQGSHDW	Maximum shadow price for reactive power generation	NRGPRC
MAXQGSHDWAT	Maximum shadow price for reactive power generation	NO
MAXQSHDW	Maximum shadow price for reactive power	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
MAXVSHDW	Maximum shadow price for voltage magnitude	VPRC
MAXVSHDWAT	Maximum shadow price for active power generation	NO
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
TOTCOSTRATE	Total cost for operating generators and storages per time. Calculated in the network, sub, zone or group as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
QLC	Total line charging	QPOW
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
COST	Total operating costs	PRCDOT
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

Summary for the derived-result properties of ESUB, which are applicable in ACPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
QLC	Total line charging	QPOW
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG

Summary for the derived-result properties of ESUB, which are applicable in UACPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
QLC	Total line charging	QPOW
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG

Summary for the derived-result properties of ESUB, which are applicable in DCUCOPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
VAMIN	Minimum voltage angle	ANGLE
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
TOTCOSTRATE	Total cost for operating generators and storages per time. Calculated in the network, sub, zone or group as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

Summary for the derived-result properties of ESUB, which are applicable in ACOPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPGSHDW	Maximum shadow price for active power generation	NRGPRC
MAXPGSHDWAT	Maximum shadow price for active power generation	NO
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
MAXQGSHDW	Maximum shadow price for reactive power generation	NRGPRC
MAXQGSHDWAT	Maximum shadow price for reactive power generation	NO
MAXQSHDW	Maximum shadow price for reactive power	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
MAXVSHDW	Maximum shadow price for voltage magnitude	VPRC
MAXVSHDWAT	Maximum shadow price for active power generation	NO
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
QLC	Total line charging	QPOW
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
COST	Total operating costs	PRCDOT
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of ESUB.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ESUB, which are applicable in ACPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ESUB, which are applicable in UACPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ESUB, which are applicable in DCUCOPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ESUB, which are applicable in ACOPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of ESUB.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ESUB, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ESUB, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ESUB, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ESUB, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

2.2. Electric zone (EZN)

A zone is a subset of nodes, branches, and externals of an electricity network. In contrast to subs, zones are node-oriented, i.e., only nodes can be assigned to a zone, and every node belongs to one zone. Branches with a FromNode and ToNode belonging to the same zone ae implicitly added to the corresponding zone. In contrast, branches with a FromNode and ToNode belonging to two different zones do not belong to any zone. Externals are also implicitly added to the zone of the node they are connected to. But all properties of a zone are determined by the nodes belonging to it.

Intro
derived-event-value
derived-result
net-input
net-read-only

Summaries for the properties and events of EZN.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-event-value properties of EZN.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of EZN, which are applicable in ACPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of EZN, which are applicable in UACPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of EZN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of EZN, which are applicable in ACOPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of EZN.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPGSHDW	Maximum shadow price for active power generation	NRGPRC
MAXPGSHDWAT	Maximum shadow price for active power generation	NO
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
MAXQGSHDW	Maximum shadow price for reactive power generation	NRGPRC
MAXQGSHDWAT	Maximum shadow price for reactive power generation	NO
MAXQSHDW	Maximum shadow price for reactive power	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
MAXVSHDW	Maximum shadow price for voltage magnitude	VPRC
MAXVSHDWAT	Maximum shadow price for active power generation	NO
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
TOTCOSTRATE	Total cost for operating generators and storages per time. Calculated in the network, sub, zone or group as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
QLC	Total line charging	QPOW
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
COST	Total operating costs	PRCDOT
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

Summary for the derived-result properties of EZN, which are applicable in ACPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
QLC	Total line charging	QPOW
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG

Summary for the derived-result properties of EZN, which are applicable in UACPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
QLC	Total line charging	QPOW
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG

Summary for the derived-result properties of EZN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
VAMIN	Minimum voltage angle	ANGLE
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
TOTCOSTRATE	Total cost for operating generators and storages per time. Calculated in the network, sub, zone or group as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

Summary for the derived-result properties of EZN, which are applicable in ACOPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPGSHDW	Maximum shadow price for active power generation	NRGPRC
MAXPGSHDWAT	Maximum shadow price for active power generation	NO
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
MAXQGSHDW	Maximum shadow price for reactive power generation	NRGPRC
MAXQGSHDWAT	Maximum shadow price for reactive power generation	NO
MAXQSHDW	Maximum shadow price for reactive power	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
MAXVSHDW	Maximum shadow price for voltage magnitude	VPRC
MAXVSHDWAT	Maximum shadow price for active power generation	NO
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
QLC	Total line charging	QPOW
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
COST	Total operating costs	PRCDOT
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of EZN.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of EZN, which are applicable in ACPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of EZN, which are applicable in UACPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of EZN, which are applicable in DCUCOPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of EZN, which are applicable in ACOPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of EZN.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EZN, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EZN, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EZN, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EZN, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

2.3. Electric group (EGRP)

A group is a sub of different child object types (e.g., nodes, branches, externals, fuels, ancillary services, hydro plants, constraints, etc.) of the whole network. In contrast to subs and zones, groups do not follow specific assignment rules. Thus, a child object can be assigned to multiple groups, and a group can have as many child objects assigned to it as there are child objects in the network.

Intro
derived-event-value
derived-result
net-input
net-read-only

Summaries for the properties and events of EGRP.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-event-value properties of EGRP.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of EGRP, which are applicable in ACPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of EGRP, which are applicable in UACPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of EGRP, which are applicable in DCUCOPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of EGRP, which are applicable in ACOPF.
Extension	Description	UnitType
PDSET	Total scheduled active power extraction by all electric demands in the network, sub, zone or group. Sum of all electric demands active power set points (PSET)	PPOW
PGSET	Total scheduled active power injection by all electric generators in the network, sub, zone or group. Sum of all electric generators active power set points (PSET)	PPOW
PCAPFGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all the in-service (InService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (InService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (InService = True)	PPOW
PCAPPV	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (InService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the network, sub, zone or group. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (InService = True)	PPOW
QDSET	Total scheduled reactive power demand	QPOW
STRCAP	Total storage capacity of all storages in the network, sub, zone or group. Sum of all maximum storages capacities (MaxCap)	NRG

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of EGRP.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPGSHDW	Maximum shadow price for active power generation	NRGPRC
MAXPGSHDWAT	Maximum shadow price for active power generation	NO
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
MAXQGSHDW	Maximum shadow price for reactive power generation	NRGPRC
MAXQGSHDWAT	Maximum shadow price for reactive power generation	NO
MAXQSHDW	Maximum shadow price for reactive power	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
MAXVSHDW	Maximum shadow price for voltage magnitude	VPRC
MAXVSHDWAT	Maximum shadow price for active power generation	NO
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
TOTCOSTRATE	Total cost for operating generators and storages per time. Calculated in the network, sub, zone or group as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
QLC	Total line charging	QPOW
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
COST	Total operating costs	PRCDOT
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

Summary for the derived-result properties of EGRP, which are applicable in ACPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
QLC	Total line charging	QPOW
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG

Summary for the derived-result properties of EGRP, which are applicable in UACPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
QLC	Total line charging	QPOW
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG

Summary for the derived-result properties of EGRP, which are applicable in DCUCOPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
VAMIN	Minimum voltage angle	ANGLE
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
TOTCOSTRATE	Total cost for operating generators and storages per time. Calculated in the network, sub, zone or group as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

Summary for the derived-result properties of EGRP, which are applicable in ACOPF.
Extension	Description	UnitType
PLMAX	Maximum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
MAXPGSHDW	Maximum shadow price for active power generation	NRGPRC
MAXPGSHDWAT	Maximum shadow price for active power generation	NO
MAXPSHDW	Maximum shadow price for nodal active power balance among all the nodes in service in the network, sub, zone or group	NRGPRC
IMAX	Maximum current	CURR
QLMAX	Maximum reactive power loss	QPOW
MAXQGSHDW	Maximum shadow price for reactive power generation	NRGPRC
MAXQGSHDWAT	Maximum shadow price for reactive power generation	NO
MAXQSHDW	Maximum shadow price for reactive power	NRGPRC
VAMAX	Maximum voltage angle	ANGLE
VMAX	Maximum voltage	VOLT
MAXVSHDW	Maximum shadow price for voltage magnitude	VPRC
MAXVSHDWAT	Maximum shadow price for active power generation	NO
PLMIN	Minimum active power loss among all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
IMIN	Minimum current	CURR
QLMIN	Minimum reactive power loss	QPOW
VAMIN	Minimum voltage angle	ANGLE
VMIN	Minimum voltage	VOLT
SOC	State of charge for all in service storages in the network, sub, zone or group. Calculated as the weighted energy average stored (in %)	PC
PFB	Active power flow balance	PPOW
PD	Total active power extraction from the network, sub, zone or group by all electric demands	PPOW
PEPS	Total active power generation from all electric prosumers in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
POUT	Total active power extraction from the network, sub, zone or group by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all electric generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection to the network, sub, zone or group by all externals. It also includes storages and hydros when discharging	PPOW
PL	Total active power loss of all branches in the network, sub, zone or group. In DCUCOPF losses are considered if INCLUDELOSSES (network) event is applied	PPOW
PLSTR	Total active power losses from all storages objects in the network, sub, zone or group. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PPHSTR	Total active power generation from all pumped hydro storages in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSHT	Total Active Power Demand by connected Shunts	PPOW
PPV	Total active power generation of all solar generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all electric storages in the network, sub, zone or group. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators in the network, sub, zone or group. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all electric demands in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators in the network, sub, zone or group. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time. Calculated as the sum of the emission rates (CO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
FuelCostRate	Total fuel cost rate per time. Calculated as the sum of the fuel rates (FuelCostRate) of all fuel generators in the network, sub, zone or group	PRCDOT
QLC	Total line charging	QPOW
NOXRATE	Total emission rate of nitrogen oxides per time. Calculated as the sum of the emission rates (NOXRATE) of all fuel generators in the network, sub, zone or group	EMDOT
COST	Total operating costs	PRCDOT
QFB	Reactive power flow balance	QPOW
QD	Total reactive power demand	QPOW
QFGEN	Total active power generation from fuel generators	QPOW
QG	Total reactive power generation	QPOW
QHGEN	Total active power generation from hydro generators	QPOW
QL	Total reactive power loss	QPOW
QSHT	Total Reactive Power Supply by connected Shunts	QPOW
QVRG	Total active power generation from variable renewable generators	QPOW
ShutDownCostRate	Total shutdown cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (ShutDownCostRate)	C
ShutDown	Total number of fuel generators in the network, sub, zone or group that have shut down between current time step and previous time step. Sum of all (ShutDown)	ND
SO2RATE	Total emission rate of sulfur dioxide per time. Calculated as the sum of the emission rates (SO2RATE) of all fuel generators in the network, sub, zone or group	EMDOT
StartUpCostRate	Total startup cost of fuel generators in the network, sub, zone or group between current time step and previous time step. Sum of all (StartUpCostRate)	C
StartUp	Total number of fuel generators in the network, sub, zone or group that have started up between current time step and previous time step. Sum of all (StartUp)	ND
STRINV	Total storage inventory of all storages in the network, sub, zone or group. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTVOMRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators in the network, sub, zone or group	PRCDOT

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of EGRP.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of EGRP, which are applicable in ACPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of EGRP, which are applicable in UACPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of EGRP, which are applicable in DCUCOPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of EGRP, which are applicable in ACOPF.
Extension	Description	UnitType
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of EGRP.
Extension	Description	UnitType
NetType	Network Type
NUMCNSTR	Number of branches in the network, sub, zone or group	NO
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EGRP, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
NUMCNSTR	Number of branches in the network, sub, zone or group	NO
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EGRP, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
NUMCNSTR	Number of branches in the network, sub, zone or group	NO
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EGRP, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
NUMCNSTR	Number of branches in the network, sub, zone or group	NO
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EGRP, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
NUMCNSTR	Number of branches in the network, sub, zone or group	NO
NUMBR	Number of branches in the network, sub, zone or group	NO
NUMXT	Number of externals in the network, sub, zone or group	NO
NUMLOOP	Number of closed loops in the network, sub, zone or group	NO
NUMNO	Number of nodes in the network, sub, zone or group	NO
ObjType	Object Type
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generators in the network, sub, zone or group	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator types in the network, sub, zone or group	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generators in the network, sub, zone or group	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generators in the network, sub, zone or group	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generators in the network, sub, zone or group	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generators in the network, sub, zone or group	PPOW
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

3. Electric node (ENO)

Nodes represent objects describing a junction among two or more electric branches, as well as a location in the electric network where power can be injected or extracted through externals (e.g., demand, supply, etc.).

Summaries for the properties and events of ENO.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of ENO.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
PSHDW	Shadow price for nodal active power balance	NRGPRC
QSHDW	Shadow price for nodal reactive power balance	NRGPRC
VA	Voltage Angle	ANGLE
VPU	Voltage magnitude per unit	PU

Summary for the base-result properties of ENO, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
VA	Voltage Angle	ANGLE
VPU	Voltage magnitude per unit	PU

Summary for the base-result properties of ENO, which are applicable in UACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU

Summary for the base-result properties of ENO, which are applicable in DCUCOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for nodal active power balance	NRGPRC
VA	Voltage Angle	ANGLE

Summary for the base-result properties of ENO, which are applicable in ACOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for nodal active power balance	NRGPRC
QSHDW	Shadow price for nodal reactive power balance	NRGPRC
VA	Voltage Angle	ANGLE
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-event-value properties of ENO.
Extension	Description	UnitType
PCAPFGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (inService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (inService = True)	PPOW
PCAPPV	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (inService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (inService = True)	PPOW
STRCAP	Total storage capacity of all storages connected to the node. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ENO, which are applicable in ACPF.
Extension	Description	UnitType
PCAPFGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (inService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (inService = True)	PPOW
PCAPPV	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (inService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (inService = True)	PPOW
STRCAP	Total storage capacity of all storages connected to the node. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ENO, which are applicable in UACPF.
Extension	Description	UnitType
PCAPFGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (inService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (inService = True)	PPOW
PCAPPV	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (inService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (inService = True)	PPOW
STRCAP	Total storage capacity of all storages connected to the node. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ENO, which are applicable in DCUCOPF.
Extension	Description	UnitType
PCAPFGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (inService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (inService = True)	PPOW
PCAPPV	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (inService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (inService = True)	PPOW
STRCAP	Total storage capacity of all storages connected to the node. Sum of all maximum storages capacities (MaxCap)	NRG

Summary for the derived-event-value properties of ENO, which are applicable in ACOPF.
Extension	Description	UnitType
PCAPFGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating fuel generators	PPOW
PCAP	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all the in-service (inService = True) and operating generators	PPOW
PCAPXGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all generic generators in service (inService = True)	PPOW
PCAPHGEN	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all hydro generators in service (inService = True)	PPOW
PCAPPV	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all solar generators in service (inService = True)	PPOW
PCAPWIND	Total available active power generation capacity in the node. Calculated as the sum of the maximum active power (PMAX) of all wind generators in service (inService = True)	PPOW
STRCAP	Total storage capacity of all storages connected to the node. Sum of all maximum storages capacities (MaxCap)	NRG

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of ENO.
Extension	Description	UnitType
P	Total active power supply minus demands from externals. Demand is the sum of demand, storage and hydro when charging. Calculated as (PIN) minus (POUT)	PPOW
PD	Total active power extraction from the node by all electric demands objects	PPOW
POUT	Total active power extraction from the node by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all generators objects connected to the node. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection from the node by all externals including storages and hydro when discharging	PPOW
PSHT	Total active power absorption(-)/injection(+) from all shunts connected to the node. Calculated as the difference between absorption (P with negative sign) and injection (P with positive sign)	PPOW
PLSTR	Total active power losses from all storages connected to the node. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all externals connected to the node. Calculated as the sum of PSET minus P	PPOW
PEPS	Total active power generation/demand from all electric prosumers connected to the node. Calculated as the sum of all active power (P)	PPOW
PPHSTR	Total active power generation/demand from all pumped hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation by solar generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all storages connected to the node. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all demands connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PHASESINUSE	Available phase conductors at the node based on the branches and generators connected to the node, valid outputs are A, B, C, AB, AC, BC or ABC
VPUAVG	Average of line-to-line voltage magnitudes of available phases at the node in per unit. Returns line-to-neutral voltage if only single phase is available	PU
CO2RATE	Total emission rate of carbon dioxide per time calculated as the sum of the emission rates (CO2RATE) of all fuel generators connected to the node	EMDOT
FuelCostRate	Total fuel cost rate per time calculated as the sum of the fuel rates (FuelCostRate) of all fuel generator(s) connected to the node	PRCDOT
NOXRATE	Total emission rate of nitrogen oxides per time calculated as the sum of the emission rates (NOXRATE) of all fuel generators connected to the node	EMDOT
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
QSHT	Reactive power injection from shunts (-) absorption / (+) injection	QPOW
ShutDown	Total number of fuel generator(s) that have shut down between current time step and previous time step calculated as the sum of shut down (ShutDown) of all fuel generator(s) connected to the node	ND
ShutDownCostRate	Total shut down cost of fuel generator(s) between current time step and previous time step calculated as the sum of shut down cost rates (ShutDownCostRate) of all fuel generators connected to the node	C
SO2RATE	Total emission rate of sulfur dioxide per time calculated as the sum of the emission rates (SO2RATE) of all fuel generators connected to the node	EMDOT
StartUp	Total number of fuel generator(s) that have started up between current time step and previous time step calculated as the sum of start up (StartUp) of all fuel generator(s) connected to the node	ND
StartUpCostRate	Total startup cost of fuel generator(s) between current time step and previous time step calculated as the sum of start up cost rates (StartUpCostRate) of all fuel generators connected to the node	C
SOC	State of charge for the in service storage(s) calculated as the weighted energy average stored (in %) of the storages connected to the node	PC
STRINV	Total storage inventory of all storages connected to the node. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
S	Magnitude of the net apparent power at the node	SPOW
TOTCOSTRATE	Total cost for operating generators and storages per time calculated as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
Q	Total reactive power supply minus demand from externals	QPOW
QD	Reactive Power Demand	QPOW
QG	Total reactive power supply from externals	QPOW
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VOMCOSTRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators connected to the node	PRCDOT

Summary for the derived-result properties of ENO, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power supply minus demands from externals. Demand is the sum of demand, storage and hydro when charging. Calculated as (PIN) minus (POUT)	PPOW
PD	Total active power extraction from the node by all electric demands objects	PPOW
POUT	Total active power extraction from the node by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all generators objects connected to the node. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection from the node by all externals including storages and hydro when discharging	PPOW
PSHT	Total active power absorption(-)/injection(+) from all shunts connected to the node. Calculated as the difference between absorption (P with negative sign) and injection (P with positive sign)	PPOW
PLSTR	Total active power losses from all storages connected to the node. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all externals connected to the node. Calculated as the sum of PSET minus P	PPOW
PEPS	Total active power generation/demand from all electric prosumers connected to the node. Calculated as the sum of all active power (P)	PPOW
PPHSTR	Total active power generation/demand from all pumped hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation by solar generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all storages connected to the node. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all demands connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators connected to the node. Calculated as the sum of PSET minus P	PPOW
QSHT	Reactive power injection from shunts (-) absorption / (+) injection	QPOW
SOC	State of charge for the in service storage(s) calculated as the weighted energy average stored (in %) of the storages connected to the node	PC
STRINV	Total storage inventory of all storages connected to the node. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
S	Magnitude of the net apparent power at the node	SPOW
Q	Total reactive power supply minus demand from externals	QPOW
QD	Reactive Power Demand	QPOW
QG	Total reactive power supply from externals	QPOW
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT

Summary for the derived-result properties of ENO, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power supply minus demands from externals. Demand is the sum of demand, storage and hydro when charging. Calculated as (PIN) minus (POUT)	PPOW
PD	Total active power extraction from the node by all electric demands objects	PPOW
POUT	Total active power extraction from the node by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all generators objects connected to the node. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection from the node by all externals including storages and hydro when discharging	PPOW
PSHT	Total active power absorption(-)/injection(+) from all shunts connected to the node. Calculated as the difference between absorption (P with negative sign) and injection (P with positive sign)	PPOW
PLSTR	Total active power losses from all storages connected to the node. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all externals connected to the node. Calculated as the sum of PSET minus P	PPOW
PEPS	Total active power generation/demand from all electric prosumers connected to the node. Calculated as the sum of all active power (P)	PPOW
PPHSTR	Total active power generation/demand from all pumped hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation by solar generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all storages connected to the node. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all demands connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PHASESINUSE	Available phase conductors at the node based on the branches and generators connected to the node, valid outputs are A, B, C, AB, AC, BC or ABC
VPUAVG	Average of line-to-line voltage magnitudes of available phases at the node in per unit. Returns line-to-neutral voltage if only single phase is available	PU
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
QSHT	Reactive power injection from shunts (-) absorption / (+) injection	QPOW
SOC	State of charge for the in service storage(s) calculated as the weighted energy average stored (in %) of the storages connected to the node	PC
STRINV	Total storage inventory of all storages connected to the node. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
S	Magnitude of the net apparent power at the node	SPOW
Q	Total reactive power supply minus demand from externals	QPOW
QD	Reactive Power Demand	QPOW
QG	Total reactive power supply from externals	QPOW
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT

Summary for the derived-result properties of ENO, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power supply minus demands from externals. Demand is the sum of demand, storage and hydro when charging. Calculated as (PIN) minus (POUT)	PPOW
PD	Total active power extraction from the node by all electric demands objects	PPOW
POUT	Total active power extraction from the node by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all generators objects connected to the node. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection from the node by all externals including storages and hydro when discharging	PPOW
PSHT	Total active power absorption(-)/injection(+) from all shunts connected to the node. Calculated as the difference between absorption (P with negative sign) and injection (P with positive sign)	PPOW
PLSTR	Total active power losses from all storages connected to the node. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all externals connected to the node. Calculated as the sum of PSET minus P	PPOW
PEPS	Total active power generation/demand from all electric prosumers connected to the node. Calculated as the sum of all active power (P)	PPOW
PPHSTR	Total active power generation/demand from all pumped hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation by solar generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all storages connected to the node. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all demands connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators connected to the node. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time calculated as the sum of the emission rates (CO2RATE) of all fuel generators connected to the node	EMDOT
FuelCostRate	Total fuel cost rate per time calculated as the sum of the fuel rates (FuelCostRate) of all fuel generator(s) connected to the node	PRCDOT
NOXRATE	Total emission rate of nitrogen oxides per time calculated as the sum of the emission rates (NOXRATE) of all fuel generators connected to the node	EMDOT
ShutDown	Total number of fuel generator(s) that have shut down between current time step and previous time step calculated as the sum of shut down (ShutDown) of all fuel generator(s) connected to the node	ND
ShutDownCostRate	Total shut down cost of fuel generator(s) between current time step and previous time step calculated as the sum of shut down cost rates (ShutDownCostRate) of all fuel generators connected to the node	C
SO2RATE	Total emission rate of sulfur dioxide per time calculated as the sum of the emission rates (SO2RATE) of all fuel generators connected to the node	EMDOT
StartUp	Total number of fuel generator(s) that have started up between current time step and previous time step calculated as the sum of start up (StartUp) of all fuel generator(s) connected to the node	ND
StartUpCostRate	Total startup cost of fuel generator(s) between current time step and previous time step calculated as the sum of start up cost rates (StartUpCostRate) of all fuel generators connected to the node	C
SOC	State of charge for the in service storage(s) calculated as the weighted energy average stored (in %) of the storages connected to the node	PC
STRINV	Total storage inventory of all storages connected to the node. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
TOTCOSTRATE	Total cost for operating generators and storages per time calculated as the sum of TOTVOMRATE and FuelCostRate. It does not include StartUpCostRate and ShutDownCostRate	PRCDOT
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
VOMCOSTRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators connected to the node	PRCDOT

Summary for the derived-result properties of ENO, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power supply minus demands from externals. Demand is the sum of demand, storage and hydro when charging. Calculated as (PIN) minus (POUT)	PPOW
PD	Total active power extraction from the node by all electric demands objects	PPOW
POUT	Total active power extraction from the node by all externals (demands, storages and hydro when charging)	PPOW
PFGEN	Total active power generation from all fuel generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PG	Total active power generation from all generators objects connected to the node. Calculated as the sum of all active power (P)	PPOW
PXGEN	Total active power generation from all generic generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PHGEN	Total active power generation from all hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PIN	Total active power injection from the node by all externals including storages and hydro when discharging	PPOW
PSHT	Total active power absorption(-)/injection(+) from all shunts connected to the node. Calculated as the difference between absorption (P with negative sign) and injection (P with positive sign)	PPOW
PLSTR	Total active power losses from all storages connected to the node. Calculated as the sum of all storages losses (PL)	PPOW
PNS	Difference between scheduled and delivered active power for all externals connected to the node. Calculated as the sum of PSET minus P	PPOW
PEPS	Total active power generation/demand from all electric prosumers connected to the node. Calculated as the sum of all active power (P)	PPOW
PPHSTR	Total active power generation/demand from all pumped hydro generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PPV	Total active power generation by solar generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PSTR	Total active power charge(-)/discharge(+) from all storages connected to the node. Calculated as the difference between charging (P with negative sign) and discharging (P with positive sign)	PPOW
PWIND	Total active power generation by wind generators connected to the node. Calculated as the sum of all active power (P)	PPOW
PNSDEM	Difference between scheduled and delivered active power for all demands connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSFGEN	Difference between scheduled and delivered active power for all fuel generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSXGEN	Difference between scheduled and delivered active power for all generic generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSHGEN	Difference between scheduled and delivered active power for all hydro generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSPV	Difference between scheduled and delivered active power for all solar generators connected to the node. Calculated as the sum of PSET minus P	PPOW
PNSWIND	Difference between scheduled and delivered active power for all wind generators connected to the node. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Total emission rate of carbon dioxide per time calculated as the sum of the emission rates (CO2RATE) of all fuel generators connected to the node	EMDOT
FuelCostRate	Total fuel cost rate per time calculated as the sum of the fuel rates (FuelCostRate) of all fuel generator(s) connected to the node	PRCDOT
NOXRATE	Total emission rate of nitrogen oxides per time calculated as the sum of the emission rates (NOXRATE) of all fuel generators connected to the node	EMDOT
QSHT	Reactive power injection from shunts (-) absorption / (+) injection	QPOW
ShutDown	Total number of fuel generator(s) that have shut down between current time step and previous time step calculated as the sum of shut down (ShutDown) of all fuel generator(s) connected to the node	ND
ShutDownCostRate	Total shut down cost of fuel generator(s) between current time step and previous time step calculated as the sum of shut down cost rates (ShutDownCostRate) of all fuel generators connected to the node	C
SO2RATE	Total emission rate of sulfur dioxide per time calculated as the sum of the emission rates (SO2RATE) of all fuel generators connected to the node	EMDOT
StartUp	Total number of fuel generator(s) that have started up between current time step and previous time step calculated as the sum of start up (StartUp) of all fuel generator(s) connected to the node	ND
StartUpCostRate	Total startup cost of fuel generator(s) between current time step and previous time step calculated as the sum of start up cost rates (StartUpCostRate) of all fuel generators connected to the node	C
SOC	State of charge for the in service storage(s) calculated as the weighted energy average stored (in %) of the storages connected to the node	PC
STRINV	Total storage inventory of all storages connected to the node. Calculated as the multiplication between state of charge (SOC) and maximum storages capacities (MaxCap)	NRG
S	Magnitude of the net apparent power at the node	SPOW
Q	Total reactive power supply minus demand from externals	QPOW
QD	Reactive Power Demand	QPOW
QG	Total reactive power supply from externals	QPOW
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VOMCOSTRATE	Total variable operational and maintenance cost per time. Calculated as the sum of the variable operational and maintenance cost rates (TOTVOMRATE) of all generators connected to the node	PRCDOT

ALL
ACPF
UACPF
ACOPF

Summary for the event-default properties of ENO.
Extension	Description	UnitType
VMAXDEF	Default maximum voltage magnitude in network per-unit	PU
VMINDEF	Default minimum voltage magnitude in network per-unit	PU

Summary for the event-default properties of ENO, which are applicable in ACPF.
Extension	Description	UnitType
VMAXDEF	Default maximum voltage magnitude in network per-unit	PU
VMINDEF	Default minimum voltage magnitude in network per-unit	PU

Summary for the event-default properties of ENO, which are applicable in UACPF.
Extension	Description	UnitType
VMAXDEF	Default maximum voltage magnitude in network per-unit	PU
VMINDEF	Default minimum voltage magnitude in network per-unit	PU

Summary for the event-default properties of ENO, which are applicable in ACOPF.
Extension	Description	UnitType
VMAXDEF	Default maximum voltage magnitude in network per-unit	PU
VMINDEF	Default minimum voltage magnitude in network per-unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of ENO.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
QREF	Reactive power reference	QPOW
VMREF	Voltage magnitude reference	PU

Summary for the event-value properties of ENO, which are applicable in ACPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
QREF	Reactive power reference	QPOW
VMREF	Voltage magnitude reference	PU

Summary for the event-value properties of ENO, which are applicable in UACPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
QREF	Reactive power reference	QPOW
VMREF	Voltage magnitude reference	PU

Summary for the event-value properties of ENO, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW

Summary for the event-value properties of ENO, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
QREF	Reactive power reference	QPOW
VMREF	Voltage magnitude reference	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of ENO.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
BaseV	Nominal voltage magnitude	VOLT
H	Elevation	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
Visible	If true, the object symbol will be visible in maps	NO
X	Cartesian X or Longitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
Y	Cartesian Y or Latitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
ZoneName	ZoneName of the zone the node belongs to

Summary for the net-input properties of ENO, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
BaseV	Nominal voltage magnitude	VOLT
H	Elevation	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
Visible	If true, the object symbol will be visible in maps	NO
X	Cartesian X or Longitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
Y	Cartesian Y or Latitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
ZoneName	ZoneName of the zone the node belongs to

Summary for the net-input properties of ENO, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
BaseV	Nominal voltage magnitude	VOLT
H	Elevation	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
Visible	If true, the object symbol will be visible in maps	NO
X	Cartesian X or Longitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
Y	Cartesian Y or Latitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
ZoneName	ZoneName of the zone the node belongs to

Summary for the net-input properties of ENO, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
BaseV	Nominal voltage magnitude	VOLT
H	Elevation	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
Visible	If true, the object symbol will be visible in maps	NO
X	Cartesian X or Longitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
Y	Cartesian Y or Latitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
ZoneName	ZoneName of the zone the node belongs to

Summary for the net-input properties of ENO, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
BaseV	Nominal voltage magnitude	VOLT
H	Elevation	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
Visible	If true, the object symbol will be visible in maps	NO
X	Cartesian X or Longitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
Y	Cartesian Y or Latitude coordinate for visualizing the node in the map. Externals assigned to the node are not displayed	XY
ZoneName	ZoneName of the zone the node belongs to

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of ENO.
Extension	Description	UnitType
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generator(s) connected to the node	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator(s) connected to the node	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generator(s) connected to the node	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generator(s) connected to the node	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generator(s) connected to the node	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generator(s) connected to the node	PPOW
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ENO, which are applicable in ACPF.
Extension	Description	UnitType
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generator(s) connected to the node	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator(s) connected to the node	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generator(s) connected to the node	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generator(s) connected to the node	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generator(s) connected to the node	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generator(s) connected to the node	PPOW
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ENO, which are applicable in UACPF.
Extension	Description	UnitType
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generator(s) connected to the node	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator(s) connected to the node	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generator(s) connected to the node	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generator(s) connected to the node	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generator(s) connected to the node	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generator(s) connected to the node	PPOW
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ENO, which are applicable in DCUCOPF.
Extension	Description	UnitType
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generator(s) connected to the node	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator(s) connected to the node	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generator(s) connected to the node	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generator(s) connected to the node	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generator(s) connected to the node	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generator(s) connected to the node	PPOW
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ENO, which are applicable in ACOPF.
Extension	Description	UnitType
NCAPFGEN	Total name plate capacity for all in service fuel generators. Calculated based on the default maximum active power (PMAXDEF) of all fuel generator(s) connected to the node	PPOW
NCAP	Total name plate capacity for all in service generators. Calculated based on the default maximum active power (PMAXDEF) of all generator(s) connected to the node	PPOW
NCAPXGEN	Total name plate capacity for all in service generic generators. Calculated based on the default maximum active power (PMAXDEF) of all generic generator(s) connected to the node	PPOW
NCAPHGEN	Total name plate capacity for all in service hydro generators. Calculated based on the default maximum active power (PMAXDEF) of all hydro generator(s) connected to the node	PPOW
NCAPPV	Total name plate capacity for all in service solar generators. Calculated based on the default maximum active power (PMAXDEF) of all solar generator(s) connected to the node	PPOW
NCAPWIND	Total name plate capacity for all in service wind generators. Calculated based on the default maximum active power (PMAXDEF) of all wind generator(s) connected to the node	PPOW
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of ENO.
Parameter	Type	Description	UnitType
OFF	State	Turn off connected externals.	NO
ON	State	Turn on connected externals.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW
QREF	Reference	Reactive power reference.	QPOW
VMAX	Constraint	Maximum voltage magnitude. Minimum: 0.	PU
VMIN	Constraint	Minimum voltage magnitude. Minimum: 0.	PU
VMREF	Reference	Voltage magnitude reference. Minimum: 0.	PU

Summary for the events of ENO, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off connected externals.	NO
ON	State	Turn on connected externals.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW
QREF	Reference	Reactive power reference.	QPOW
VMAX	Constraint	Maximum voltage magnitude. Minimum: 0.	PU
VMIN	Constraint	Minimum voltage magnitude. Minimum: 0.	PU
VMREF	Reference	Voltage magnitude reference. Minimum: 0.	PU

Summary for the events of ENO, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off connected externals.	NO
ON	State	Turn on connected externals.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW
QREF	Reference	Reactive power reference.	QPOW
VMAX	Constraint	Maximum voltage magnitude. Minimum: 0.	PU
VMIN	Constraint	Minimum voltage magnitude. Minimum: 0.	PU
VMREF	Reference	Voltage magnitude reference. Minimum: 0.	PU

Summary for the events of ENO, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off connected externals.	NO
ON	State	Turn on connected externals.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW

Summary for the events of ENO, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off connected externals.	NO
ON	State	Turn on connected externals.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW
QREF	Reference	Reactive power reference.	QPOW
VMAX	Constraint	Maximum voltage magnitude. Minimum: 0.	PU
VMIN	Constraint	Minimum voltage magnitude. Minimum: 0.	PU
VMREF	Reference	Voltage magnitude reference. Minimum: 0.	PU

4. Electric branch (EBR)

A branch is a directed connection between a pair of nodes. For each branch, one of the two nodes is referred to as FromNode and the other as ToNode. The flow along a branch is positive if the flow goes from the FromNode to the ToNode, and the flow is negative for the reversed direction.

An electric branch is used to model facilities that have an inlet, an outlet, and a flow direction, such as electric lines and electric transformers.

4.1. Line (LI)

A line is an object which models the transmission of electricity between two connected locations.

Summaries for the properties and events of LI.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of LI.
Extension	Description	UnitType
P	Active power flow through branch in DC-Scenarios	PPOW
IAPHASEA	Phase angle of current flowing through in the middle section of PI model of Phase A directed from FromNode to ToNode	ANGLE
IAPHASEB	Phase angle of current flowing through in the middle section of PI model of Phase B directed from FromNode to ToNode	ANGLE
IAPHASEC	Phase angle of current flowing through in the middle section of PI model of Phase C directed from FromNode to ToNode	ANGLE
PSHDW	Shadow price for maximum active power limit on the branch	NRGPRC
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current in the middle section of PI model directed from FromNode to ToNode	PU
IPHASEB	Magnitude of phase B current in the middle section of PI model directed from FromNode to ToNode	PU
IPHASEC	Magnitude of phase C current in the middle section of PI model directed from FromNode to ToNode	PU
STATEPHASEA	Current operating state of Phase A. Permitted states are ON or OFF
STATEPHASEB	Current operating state of Phase B. Permitted states are ON or OFF
STATEPHASEC	Current operating state of Phase C. Permitted states are ON or OFF

Summary for the base-result properties of LI, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of LI, which are applicable in UACPF.
Extension	Description	UnitType
IAPHASEA	Phase angle of current flowing through in the middle section of PI model of Phase A directed from FromNode to ToNode	ANGLE
IAPHASEB	Phase angle of current flowing through in the middle section of PI model of Phase B directed from FromNode to ToNode	ANGLE
IAPHASEC	Phase angle of current flowing through in the middle section of PI model of Phase C directed from FromNode to ToNode	ANGLE
IPHASEA	Magnitude of phase A current in the middle section of PI model directed from FromNode to ToNode	PU
IPHASEB	Magnitude of phase B current in the middle section of PI model directed from FromNode to ToNode	PU
IPHASEC	Magnitude of phase C current in the middle section of PI model directed from FromNode to ToNode	PU
STATEPHASEA	Current operating state of Phase A. Permitted states are ON or OFF
STATEPHASEB	Current operating state of Phase B. Permitted states are ON or OFF
STATEPHASEC	Current operating state of Phase C. Permitted states are ON or OFF

Summary for the base-result properties of LI, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Active power flow through branch in DC-Scenarios	PPOW
PSHDW	Shadow price for maximum active power limit on the branch	NRGPRC
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of LI, which are applicable in ACOPF.
Extension	Description	UnitType
PSHDW	Shadow price for maximum active power limit on the branch	NRGPRC
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of LI.
Extension	Description	UnitType
PF	Total active power flow (+) leaving / (-) entering the FromNode	PPOW
PFPHASEA	Active power flow in Phase A (+) leaving / (-) entering the FromNode	PPOW
PFPHASEB	Active power flow in Phase B (+) leaving / (-) entering the FromNode	PPOW
PFPHASEC	Active power flow in Phase C (+) leaving / (-) entering the FromNode	PPOW
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLPPHASEA	Phase A active power loading calculated as a ratio between active power and maximum active power	PC
LLPPHASEB	Phase B active power loading calculated as a ratio between active power and maximum active power	PC
LLPPHASEC	Phase C active power loading calculated as a ratio between active power and maximum active power	PC
PL	Total active power loss in the branch	PPOW
PLPHASEA	Active power loss in Phase A	PPOW
PLPHASEB	Active power loss in Phase B	PPOW
PLPHASEC	Active power loss in Phase C	PPOW
PT	Total active power flow (+) leaving / (-) entering the ToNode	PPOW
PTPHASEA	Active power flow in Phase A (+) leaving / (-) entering the ToNode	PPOW
PTPHASEB	Active power flow in Phase B (+) leaving / (-) entering the ToNode	PPOW
PTPHASEC	Active power flow in Phase C (+) leaving / (-) entering the ToNode	PPOW
SF	Total apparent power passing through the branch, next to "from" node, of all the phases of parallel branches	SPOW
SFPHASEA	Apparent power passing through Phase A, next to "from" node	SPOW
SFPHASEB	Apparent power passing through Phase B, next to "from" node	SPOW
SFPHASEC	Apparent power passing through Phase C, next to "from" node	SPOW
LLS	Apparent power loading given as ratio between apparent power and maximum apparent power (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLSPHASEA	Phase A apparent power loading given as ratio between apparent power and maximum apparent power	PC
LLSPHASEB	Phase B apparent power loading given as ratio between apparent power and maximum apparent power	PC
LLSPHASEC	Phase C apparent power loading given as ratio between apparent power and maximum apparent power	PC
ST	Total apparent power passing through the branch, next to "to" node, of all the phases of parallel branches	SPOW
STPHASEA	Apparent power passing through Phase A, next to "to" node	SPOW
STPHASEB	Apparent power passing through Phase B, next to "to" node	SPOW
STPHASEC	Apparent power passing through Phase C, next to "to" node	SPOW
QLCF	Charging reactive power FromNode side	QPOW
QLCT	Charging reactive power ToNode side	QPOW
I	Magnitude of the current in the middle part of PI-model directed from the FromNode to ToNode	CURR
IA	Phase angle of the current in the middle part of PI-model directed from FromNode to ToNode	ANGLE
IAF	Phase angle of current flowing into FromNode	ANGLE
IAFPHASEA	Phase angle of phase A current leaving FromNode	ANGLE
IAFPHASEB	Phase angle of phase B current leaving FromNode	ANGLE
IAFPHASEC	Phase angle of phase C current leaving FromNode	ANGLE
IAT	Phase angle of current flowing into ToNode	ANGLE
IATPHASEA	Phase angle of phase A current leaving ToNode	ANGLE
IATPHASEB	Phase angle of phase B current leaving ToNode	ANGLE
IATPHASEC	Phase angle of phase C current leaving ToNode	ANGLE
LLI	Current loading given as ratio between current and maximum current (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLIPHASEA	Phase A current loading given as ratio between current and maximum current	PC
LLIPHASEB	Phase B current loading given as ratio between current and maximum current	PC
LLIPHASEC	Phase C current loading given as ratio between current and maximum current	PC
IF	Magnitude of the current flowing into the branch from the FromNode assuming a balanced three-phase system	CURR
IFPHASEA	Magnitude of phase A current leaving FromNode	CURR
IFPHASEB	Magnitude of phase B current leaving FromNode	CURR
IFPHASEC	Magnitude of phase C current leaving FromNode	CURR
IT	Magnitude of the current flowing into the branch from the ToNode assuming a balanced three-phase system	CURR
ITPHASEA	Magnitude of phase A current leaving ToNode	CURR
ITPHASEB	Magnitude of phase B current leaving ToNode	CURR
ITPHASEC	Magnitude of phase C current leaving ToNode	CURR
IPU	Magnitude of the current in the middle part of PI-model in network per unit directed from FromNode to ToNode	PU
IAFNEUTRAL	Phase angle of the neutral current leaving the neutral point on the From side	ANGLE
IATNEUTRAL	Phase angle of the neutral current leaving the neutral point on the To side	ANGLE
IFNEUTRAL	Magnitude of the neutral current leaving the neutral point on the From side	CURR
ITNEUTRAL	Magnitude of the neutral current leaving the neutral point on the To side	CURR
QF	Total reactive power flow (+) leaving / (-) entering the FromNode	QPOW
QFPHASEA	Reactive power flow in Phase A (+) leaving / (-) entering the FromNode	QPOW
QFPHASEB	Reactive power flow in Phase B (+) leaving / (-) entering the FromNode	QPOW
QFPHASEC	Reactive power flow in Phase C (+) leaving / (-) entering the FromNode	QPOW
QL	Total reactive power consumption in the series part	QPOW
QLPHASEA	Reactive power consumption in the series part of Phase A	QPOW
QLPHASEB	Reactive power consumption in the series part of Phase B	QPOW
QLPHASEC	Reactive power consumption in the series part of Phase C	QPOW
QT	Total reactive power flow (+) leaving / (-) entering the ToNode	QPOW
QTPHASEA	Reactive power flow in Phase A (+) leaving / (-) entering the ToNode	QPOW
QTPHASEB	Reactive power flow in Phase B (+) leaving / (-) entering the ToNode	QPOW
QTPHASEC	Reactive power flow in Phase C (+) leaving / (-) entering the ToNode	QPOW
QLC	Total charging reactive power flowing through the shunt part	QPOW
QLCPHASEA	Total charging reactive power flowing through the shunt part of Phase A	QPOW
QLCPHASEB	Total charging reactive power flowing through the shunt part of Phase B	QPOW
QLCPHASEC	Total charging reactive power flowing through the shunt part of Phase C	QPOW
VAD	Voltage angle difference calculated as the difference between "ToNode" and "FromNode" voltage angles (VA)	ANGLE
VADPHASEA	Voltage angle difference on Phase A, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VADPHASEB	Voltage angle difference on Phase B, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VADPHASEC	Voltage angle difference on Phase C, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VAF	Voltage angle at FromNode	ANGLE
VAFPHASEA	Voltage angle at FromNode of Phase A	ANGLE
VAFPHASEB	Voltage angle at FromNode of Phase B	ANGLE
VAFPHASEC	Voltage angle at FromNode of Phase C	ANGLE
VAT	Voltage angle at ToNode	ANGLE
VATPHASEA	Voltage angle at ToNode of Phase A	ANGLE
VATPHASEB	Voltage angle at ToNode of Phase B	ANGLE
VATPHASEC	Voltage angle at ToNode of Phase C	ANGLE
VMD	Voltage magnitude of FromNode minus that of ToNode	VOLT
VMDPHASEA	Voltage magnitude of the phase A of FromNode minus that of ToNode	VOLT
VMDPHASEB	Voltage magnitude of the phase B of FromNode minus that of ToNode	VOLT
VMDPHASEC	Voltage magnitude of the phase C of FromNode minus that of ToNode	VOLT
VMF	Voltage magnitude at FromNode (for UACPF, the average line-to-line voltage at the FromNode is taken)	VOLT
VMFPHASEA	Voltage magnitude at FromNode of Phase A	VOLT
VMFPHASEB	Voltage magnitude at FromNode of Phase B	VOLT
VMFPHASEC	Voltage magnitude at FromNode of Phase C	VOLT
VMR	Voltage magnitude ratio, ratio between ToNode and FromNode voltage magnitudes (for UACPF, the ratio between the average line-to-line voltages at the two sides is taken)	ND
VMRPHASEA	Phase A voltage magnitude ratio between ToNode and FromNode voltage magnitudes	ND
VMRPHASEB	Phase B voltage magnitude ratio between ToNode and FromNode voltage magnitudes	ND
VMRPHASEC	Phase C voltage magnitude ratio between ToNode and FromNode voltage magnitudes of Phase C	ND
VMT	Voltage magnitude ToNode (for UACPF, the average line-to-line voltage at the ToNode is taken)	VOLT
VMTPHASEA	Voltage magnitude at ToNode of Phase A	VOLT
VMTPHASEB	Voltage magnitude at ToNode of Phase B	VOLT
VMTPHASEC	Voltage magnitude at ToNode of Phase C	VOLT

Summary for the derived-result properties of LI, which are applicable in ACPF.
Extension	Description	UnitType
PF	Total active power flow (+) leaving / (-) entering the FromNode	PPOW
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
PL	Total active power loss in the branch	PPOW
PT	Total active power flow (+) leaving / (-) entering the ToNode	PPOW
SF	Total apparent power passing through the branch, next to "from" node, of all the phases of parallel branches	SPOW
LLS	Apparent power loading given as ratio between apparent power and maximum apparent power (for unbalanced system, it returns the maximum loading among the three phases)	PC
ST	Total apparent power passing through the branch, next to "to" node, of all the phases of parallel branches	SPOW
QLCF	Charging reactive power FromNode side	QPOW
QLCT	Charging reactive power ToNode side	QPOW
I	Magnitude of the current in the middle part of PI-model directed from the FromNode to ToNode	CURR
IA	Phase angle of the current in the middle part of PI-model directed from FromNode to ToNode	ANGLE
IAF	Phase angle of current flowing into FromNode	ANGLE
IAT	Phase angle of current flowing into ToNode	ANGLE
LLI	Current loading given as ratio between current and maximum current (for unbalanced system, it returns the maximum loading among the three phases)	PC
IF	Magnitude of the current flowing into the branch from the FromNode assuming a balanced three-phase system	CURR
IT	Magnitude of the current flowing into the branch from the ToNode assuming a balanced three-phase system	CURR
IPU	Magnitude of the current in the middle part of PI-model in network per unit directed from FromNode to ToNode	PU
QF	Total reactive power flow (+) leaving / (-) entering the FromNode	QPOW
QL	Total reactive power consumption in the series part	QPOW
QT	Total reactive power flow (+) leaving / (-) entering the ToNode	QPOW
QLC	Total charging reactive power flowing through the shunt part	QPOW
VAD	Voltage angle difference calculated as the difference between "ToNode" and "FromNode" voltage angles (VA)	ANGLE
VAF	Voltage angle at FromNode	ANGLE
VAT	Voltage angle at ToNode	ANGLE
VMD	Voltage magnitude of FromNode minus that of ToNode	VOLT
VMF	Voltage magnitude at FromNode (for UACPF, the average line-to-line voltage at the FromNode is taken)	VOLT
VMR	Voltage magnitude ratio, ratio between ToNode and FromNode voltage magnitudes (for UACPF, the ratio between the average line-to-line voltages at the two sides is taken)	ND
VMT	Voltage magnitude ToNode (for UACPF, the average line-to-line voltage at the ToNode is taken)	VOLT

Summary for the derived-result properties of LI, which are applicable in UACPF.
Extension	Description	UnitType
PF	Total active power flow (+) leaving / (-) entering the FromNode	PPOW
PFPHASEA	Active power flow in Phase A (+) leaving / (-) entering the FromNode	PPOW
PFPHASEB	Active power flow in Phase B (+) leaving / (-) entering the FromNode	PPOW
PFPHASEC	Active power flow in Phase C (+) leaving / (-) entering the FromNode	PPOW
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLPPHASEA	Phase A active power loading calculated as a ratio between active power and maximum active power	PC
LLPPHASEB	Phase B active power loading calculated as a ratio between active power and maximum active power	PC
LLPPHASEC	Phase C active power loading calculated as a ratio between active power and maximum active power	PC
PL	Total active power loss in the branch	PPOW
PLPHASEA	Active power loss in Phase A	PPOW
PLPHASEB	Active power loss in Phase B	PPOW
PLPHASEC	Active power loss in Phase C	PPOW
PT	Total active power flow (+) leaving / (-) entering the ToNode	PPOW
PTPHASEA	Active power flow in Phase A (+) leaving / (-) entering the ToNode	PPOW
PTPHASEB	Active power flow in Phase B (+) leaving / (-) entering the ToNode	PPOW
PTPHASEC	Active power flow in Phase C (+) leaving / (-) entering the ToNode	PPOW
SF	Total apparent power passing through the branch, next to "from" node, of all the phases of parallel branches	SPOW
SFPHASEA	Apparent power passing through Phase A, next to "from" node	SPOW
SFPHASEB	Apparent power passing through Phase B, next to "from" node	SPOW
SFPHASEC	Apparent power passing through Phase C, next to "from" node	SPOW
LLS	Apparent power loading given as ratio between apparent power and maximum apparent power (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLSPHASEA	Phase A apparent power loading given as ratio between apparent power and maximum apparent power	PC
LLSPHASEB	Phase B apparent power loading given as ratio between apparent power and maximum apparent power	PC
LLSPHASEC	Phase C apparent power loading given as ratio between apparent power and maximum apparent power	PC
ST	Total apparent power passing through the branch, next to "to" node, of all the phases of parallel branches	SPOW
STPHASEA	Apparent power passing through Phase A, next to "to" node	SPOW
STPHASEB	Apparent power passing through Phase B, next to "to" node	SPOW
STPHASEC	Apparent power passing through Phase C, next to "to" node	SPOW
IAFPHASEA	Phase angle of phase A current leaving FromNode	ANGLE
IAFPHASEB	Phase angle of phase B current leaving FromNode	ANGLE
IAFPHASEC	Phase angle of phase C current leaving FromNode	ANGLE
IATPHASEA	Phase angle of phase A current leaving ToNode	ANGLE
IATPHASEB	Phase angle of phase B current leaving ToNode	ANGLE
IATPHASEC	Phase angle of phase C current leaving ToNode	ANGLE
LLI	Current loading given as ratio between current and maximum current (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLIPHASEA	Phase A current loading given as ratio between current and maximum current	PC
LLIPHASEB	Phase B current loading given as ratio between current and maximum current	PC
LLIPHASEC	Phase C current loading given as ratio between current and maximum current	PC
IFPHASEA	Magnitude of phase A current leaving FromNode	CURR
IFPHASEB	Magnitude of phase B current leaving FromNode	CURR
IFPHASEC	Magnitude of phase C current leaving FromNode	CURR
ITPHASEA	Magnitude of phase A current leaving ToNode	CURR
ITPHASEB	Magnitude of phase B current leaving ToNode	CURR
ITPHASEC	Magnitude of phase C current leaving ToNode	CURR
IAFNEUTRAL	Phase angle of the neutral current leaving the neutral point on the From side	ANGLE
IATNEUTRAL	Phase angle of the neutral current leaving the neutral point on the To side	ANGLE
IFNEUTRAL	Magnitude of the neutral current leaving the neutral point on the From side	CURR
ITNEUTRAL	Magnitude of the neutral current leaving the neutral point on the To side	CURR
QF	Total reactive power flow (+) leaving / (-) entering the FromNode	QPOW
QFPHASEA	Reactive power flow in Phase A (+) leaving / (-) entering the FromNode	QPOW
QFPHASEB	Reactive power flow in Phase B (+) leaving / (-) entering the FromNode	QPOW
QFPHASEC	Reactive power flow in Phase C (+) leaving / (-) entering the FromNode	QPOW
QL	Total reactive power consumption in the series part	QPOW
QLPHASEA	Reactive power consumption in the series part of Phase A	QPOW
QLPHASEB	Reactive power consumption in the series part of Phase B	QPOW
QLPHASEC	Reactive power consumption in the series part of Phase C	QPOW
QT	Total reactive power flow (+) leaving / (-) entering the ToNode	QPOW
QTPHASEA	Reactive power flow in Phase A (+) leaving / (-) entering the ToNode	QPOW
QTPHASEB	Reactive power flow in Phase B (+) leaving / (-) entering the ToNode	QPOW
QTPHASEC	Reactive power flow in Phase C (+) leaving / (-) entering the ToNode	QPOW
QLC	Total charging reactive power flowing through the shunt part	QPOW
QLCPHASEA	Total charging reactive power flowing through the shunt part of Phase A	QPOW
QLCPHASEB	Total charging reactive power flowing through the shunt part of Phase B	QPOW
QLCPHASEC	Total charging reactive power flowing through the shunt part of Phase C	QPOW
VADPHASEA	Voltage angle difference on Phase A, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VADPHASEB	Voltage angle difference on Phase B, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VADPHASEC	Voltage angle difference on Phase C, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VAFPHASEA	Voltage angle at FromNode of Phase A	ANGLE
VAFPHASEB	Voltage angle at FromNode of Phase B	ANGLE
VAFPHASEC	Voltage angle at FromNode of Phase C	ANGLE
VATPHASEA	Voltage angle at ToNode of Phase A	ANGLE
VATPHASEB	Voltage angle at ToNode of Phase B	ANGLE
VATPHASEC	Voltage angle at ToNode of Phase C	ANGLE
VMDPHASEA	Voltage magnitude of the phase A of FromNode minus that of ToNode	VOLT
VMDPHASEB	Voltage magnitude of the phase B of FromNode minus that of ToNode	VOLT
VMDPHASEC	Voltage magnitude of the phase C of FromNode minus that of ToNode	VOLT
VMF	Voltage magnitude at FromNode (for UACPF, the average line-to-line voltage at the FromNode is taken)	VOLT
VMFPHASEA	Voltage magnitude at FromNode of Phase A	VOLT
VMFPHASEB	Voltage magnitude at FromNode of Phase B	VOLT
VMFPHASEC	Voltage magnitude at FromNode of Phase C	VOLT
VMR	Voltage magnitude ratio, ratio between ToNode and FromNode voltage magnitudes (for UACPF, the ratio between the average line-to-line voltages at the two sides is taken)	ND
VMRPHASEA	Phase A voltage magnitude ratio between ToNode and FromNode voltage magnitudes	ND
VMRPHASEB	Phase B voltage magnitude ratio between ToNode and FromNode voltage magnitudes	ND
VMRPHASEC	Phase C voltage magnitude ratio between ToNode and FromNode voltage magnitudes of Phase C	ND
VMT	Voltage magnitude ToNode (for UACPF, the average line-to-line voltage at the ToNode is taken)	VOLT
VMTPHASEA	Voltage magnitude at ToNode of Phase A	VOLT
VMTPHASEB	Voltage magnitude at ToNode of Phase B	VOLT
VMTPHASEC	Voltage magnitude at ToNode of Phase C	VOLT

Summary for the derived-result properties of LI, which are applicable in DCUCOPF.
Extension	Description	UnitType
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
PL	Total active power loss in the branch	PPOW
VAD	Voltage angle difference calculated as the difference between "ToNode" and "FromNode" voltage angles (VA)	ANGLE
VAF	Voltage angle at FromNode	ANGLE
VAT	Voltage angle at ToNode	ANGLE

Summary for the derived-result properties of LI, which are applicable in ACOPF.
Extension	Description	UnitType
PF	Total active power flow (+) leaving / (-) entering the FromNode	PPOW
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
PL	Total active power loss in the branch	PPOW
PT	Total active power flow (+) leaving / (-) entering the ToNode	PPOW
SF	Total apparent power passing through the branch, next to "from" node, of all the phases of parallel branches	SPOW
LLS	Apparent power loading given as ratio between apparent power and maximum apparent power (for unbalanced system, it returns the maximum loading among the three phases)	PC
ST	Total apparent power passing through the branch, next to "to" node, of all the phases of parallel branches	SPOW
QLCF	Charging reactive power FromNode side	QPOW
QLCT	Charging reactive power ToNode side	QPOW
I	Magnitude of the current in the middle part of PI-model directed from the FromNode to ToNode	CURR
IA	Phase angle of the current in the middle part of PI-model directed from FromNode to ToNode	ANGLE
IAF	Phase angle of current flowing into FromNode	ANGLE
IAT	Phase angle of current flowing into ToNode	ANGLE
LLI	Current loading given as ratio between current and maximum current (for unbalanced system, it returns the maximum loading among the three phases)	PC
IF	Magnitude of the current flowing into the branch from the FromNode assuming a balanced three-phase system	CURR
IT	Magnitude of the current flowing into the branch from the ToNode assuming a balanced three-phase system	CURR
IPU	Magnitude of the current in the middle part of PI-model in network per unit directed from FromNode to ToNode	PU
QF	Total reactive power flow (+) leaving / (-) entering the FromNode	QPOW
QL	Total reactive power consumption in the series part	QPOW
QT	Total reactive power flow (+) leaving / (-) entering the ToNode	QPOW
QLC	Total charging reactive power flowing through the shunt part	QPOW
VAD	Voltage angle difference calculated as the difference between "ToNode" and "FromNode" voltage angles (VA)	ANGLE
VAF	Voltage angle at FromNode	ANGLE
VAT	Voltage angle at ToNode	ANGLE
VMD	Voltage magnitude of FromNode minus that of ToNode	VOLT
VMF	Voltage magnitude at FromNode (for UACPF, the average line-to-line voltage at the FromNode is taken)	VOLT
VMR	Voltage magnitude ratio, ratio between ToNode and FromNode voltage magnitudes (for UACPF, the ratio between the average line-to-line voltages at the two sides is taken)	ND
VMT	Voltage magnitude ToNode (for UACPF, the average line-to-line voltage at the ToNode is taken)	VOLT

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of LI.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power flow (PMAX). This property is the default value for the PMAXPRC property if no PMAXPRC event is defined in a scenario. Penalty is calculated as (P-PMAX) * PMAXPRC	NRGPRC
SMAXDEF	Default maximum apparent power	SPOW
IMAXDEF	Default maximum current magnitude in each phase of a balanced three-phase branch	CURR
PMAXREVDEF	Default maximum active power in the negative flow direction. It constrains the active power flow only in the negative flow direction, i.e. in the "ToNode" to "FromNode" flow direction. This property is the default value for the PMAXREV property if no PMAXREV event is defined in a scenario. It is only considered if a REVON event is defined for the electric network	PPOW
PMAXREVPRCDEF	Default penalty price for exceeding the maximum active power in negative flow direction (PMAXREV), i.e. "ToNode" to "FromNode" flow direction. This property is the default value for the PMAXREVPRC property if no PMAXREVPRC event is defined in a scenario. Penalty is calculated as (P-PMAXREV) * PMAXREVPRC	NRGPRC

Summary for the event-default properties of LI, which are applicable in ACPF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
SMAXDEF	Default maximum apparent power	SPOW
IMAXDEF	Default maximum current magnitude in each phase of a balanced three-phase branch	CURR

Summary for the event-default properties of LI, which are applicable in UACPF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
SMAXDEF	Default maximum apparent power	SPOW
IMAXDEF	Default maximum current magnitude in each phase of a balanced three-phase branch	CURR

Summary for the event-default properties of LI, which are applicable in DCUCOPF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power flow (PMAX). This property is the default value for the PMAXPRC property if no PMAXPRC event is defined in a scenario. Penalty is calculated as (P-PMAX) * PMAXPRC	NRGPRC
PMAXREVDEF	Default maximum active power in the negative flow direction. It constrains the active power flow only in the negative flow direction, i.e. in the "ToNode" to "FromNode" flow direction. This property is the default value for the PMAXREV property if no PMAXREV event is defined in a scenario. It is only considered if a REVON event is defined for the electric network	PPOW
PMAXREVPRCDEF	Default penalty price for exceeding the maximum active power in negative flow direction (PMAXREV), i.e. "ToNode" to "FromNode" flow direction. This property is the default value for the PMAXREVPRC property if no PMAXREVPRC event is defined in a scenario. Penalty is calculated as (P-PMAXREV) * PMAXREVPRC	NRGPRC

Summary for the event-default properties of LI, which are applicable in ACOPF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
SMAXDEF	Default maximum apparent power	SPOW
IMAXDEF	Default maximum current magnitude in each phase of a balanced three-phase branch	CURR

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of LI.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
PMAXPRC	Penalty price for maximum active power flow through the branch. Equal to PMAXPRCDEF property unless a PMAXPRC event is defined for the scenario. Penalty is calculated as (P-PMAX) * PMAXPRC	NRGPRC
SMAX	Maximum apparent power	SPOW
IMAX	Maximum current magnitude in each phase of a balanced three-phase branch	CURR
PMAXREVPRC	Penalty price for maximum active power in reverse branch flow direction (PMAXREV). Equal to PMAXREVPRCDEF property unless a PMAXREVPRC event is defined for the scenario. Penalty is calculated as (P-PMAXREV) * PMAXREVPRC	NRGPRC
PMAXREV	Maximum active power in reverse branch flow direction (positive number, can be greater than PMAX, only considered if a REVON event is defined for the electric network). Equal to PMAXREVDEF property unless a PMAXREV event is defined for the scenario	PPOW

Summary for the event-value properties of LI, which are applicable in ACPF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
SMAX	Maximum apparent power	SPOW
IMAX	Maximum current magnitude in each phase of a balanced three-phase branch	CURR

Summary for the event-value properties of LI, which are applicable in UACPF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
SMAX	Maximum apparent power	SPOW
IMAX	Maximum current magnitude in each phase of a balanced three-phase branch	CURR

Summary for the event-value properties of LI, which are applicable in DCUCOPF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
PMAXPRC	Penalty price for maximum active power flow through the branch. Equal to PMAXPRCDEF property unless a PMAXPRC event is defined for the scenario. Penalty is calculated as (P-PMAX) * PMAXPRC	NRGPRC
PMAXREVPRC	Penalty price for maximum active power in reverse branch flow direction (PMAXREV). Equal to PMAXREVPRCDEF property unless a PMAXREVPRC event is defined for the scenario. Penalty is calculated as (P-PMAXREV) * PMAXREVPRC	NRGPRC
PMAXREV	Maximum active power in reverse branch flow direction (positive number, can be greater than PMAX, only considered if a REVON event is defined for the electric network). Equal to PMAXREVDEF property unless a PMAXREV event is defined for the scenario	PPOW

Summary for the event-value properties of LI, which are applicable in ACOPF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
SMAX	Maximum apparent power	SPOW
IMAX	Maximum current magnitude in each phase of a balanced three-phase branch	CURR

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of LI.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the per unit lenth properties of line are used
XXDEF	Positive sequence series reactance in line per unit system. Series capacitor is represented by negative value. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
BBDEF	Positive sequence shunt susceptance in branch per unit system. Used if "CalcImp" is false. Must be non-negative for electric line, because the shunt is capacitive	PU
XX0DEF	Zero sequence line reactance in line per unit system. Series capacitors can be modeled with negative values. The value is ignored for sigle-phase lines	PU
RR0DEF	Zero sequence line resistance in line per unit system. The value is ignored for single-phase lines	PU
BB0DEF	Zero sequence line susceptance in line per unit system. The value is ignored for single-phase lines	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
L	Total length of electric line	L
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
PHASESINUSE	Identifies which phases of the line are connected, valid values are A, B, C, AB, AC, BC or ABC.
XXL	Positive sequence line reactance per length	RRL
RRL	Positive sequence line resistance per unit length	RRL
BBL	Positive sequence line susceptance per unit length	GGL
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
SubName	Sub the branch belongs to
ToName	Name of ToNode
Visible	If true, the object symbol will be visible in maps	NO
XX0L	Zero sequence line reactance per unit length. The value is ignored for single-phase lines	RRL
RR0L	Zero sequence line resistance per unit length. The value is ignored for single-phase lines	RRL
BB0L	Zero sequence line susceptance per unit length. The value is ignored for single-phase lines	GGL

Summary for the net-input properties of LI, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the per unit lenth properties of line are used
XXDEF	Positive sequence series reactance in line per unit system. Series capacitor is represented by negative value. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
BBDEF	Positive sequence shunt susceptance in branch per unit system. Used if "CalcImp" is false. Must be non-negative for electric line, because the shunt is capacitive	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
L	Total length of electric line	L
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
PHASESINUSE	Identifies which phases of the line are connected, valid values are A, B, C, AB, AC, BC or ABC.
XXL	Positive sequence line reactance per length	RRL
RRL	Positive sequence line resistance per unit length	RRL
BBL	Positive sequence line susceptance per unit length	GGL
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
SubName	Sub the branch belongs to
ToName	Name of ToNode
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of LI, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the per unit lenth properties of line are used
XXDEF	Positive sequence series reactance in line per unit system. Series capacitor is represented by negative value. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
BBDEF	Positive sequence shunt susceptance in branch per unit system. Used if "CalcImp" is false. Must be non-negative for electric line, because the shunt is capacitive	PU
XX0DEF	Zero sequence line reactance in line per unit system. Series capacitors can be modeled with negative values. The value is ignored for sigle-phase lines	PU
RR0DEF	Zero sequence line resistance in line per unit system. The value is ignored for single-phase lines	PU
BB0DEF	Zero sequence line susceptance in line per unit system. The value is ignored for single-phase lines	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
L	Total length of electric line	L
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
PHASESINUSE	Identifies which phases of the line are connected, valid values are A, B, C, AB, AC, BC or ABC.
XXL	Positive sequence line reactance per length	RRL
RRL	Positive sequence line resistance per unit length	RRL
BBL	Positive sequence line susceptance per unit length	GGL
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
SubName	Sub the branch belongs to
ToName	Name of ToNode
Visible	If true, the object symbol will be visible in maps	NO
XX0L	Zero sequence line reactance per unit length. The value is ignored for single-phase lines	RRL
RR0L	Zero sequence line resistance per unit length. The value is ignored for single-phase lines	RRL
BB0L	Zero sequence line susceptance per unit length. The value is ignored for single-phase lines	GGL

Summary for the net-input properties of LI, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the per unit lenth properties of line are used
XXDEF	Positive sequence series reactance in line per unit system. Series capacitor is represented by negative value. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
L	Total length of electric line	L
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXL	Positive sequence line reactance per length	RRL
RRL	Positive sequence line resistance per unit length	RRL
SubName	Sub the branch belongs to
ToName	Name of ToNode
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of LI, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the per unit lenth properties of line are used
XXDEF	Positive sequence series reactance in line per unit system. Series capacitor is represented by negative value. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
BBDEF	Positive sequence shunt susceptance in branch per unit system. Used if "CalcImp" is false. Must be non-negative for electric line, because the shunt is capacitive	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
L	Total length of electric line	L
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXL	Positive sequence line reactance per length	RRL
RRL	Positive sequence line resistance per unit length	RRL
BBL	Positive sequence line susceptance per unit length	GGL
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
SubName	Sub the branch belongs to
ToName	Name of ToNode
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of LI.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
LGEO	Length According to Map Coordinates	L
LD	Difference between actual pipeline length and geographic length	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
BB	Positive sequence shunt susceptance in network per unit system	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object
XX0	Zero sequence series reactance in network per unit system.	PU
RR0	Zero sequence series resistance in network per unit system.	PU
BB0	Zero sequences shunt susceptance in network per unit system.	PU

Summary for the net-read-only properties of LI, which are applicable in ACPF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
LGEO	Length According to Map Coordinates	L
LD	Difference between actual pipeline length and geographic length	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
BB	Positive sequence shunt susceptance in network per unit system	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of LI, which are applicable in UACPF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
LGEO	Length According to Map Coordinates	L
LD	Difference between actual pipeline length and geographic length	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
BB	Positive sequence shunt susceptance in network per unit system	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object
XX0	Zero sequence series reactance in network per unit system.	PU
RR0	Zero sequence series resistance in network per unit system.	PU
BB0	Zero sequences shunt susceptance in network per unit system.	PU

Summary for the net-read-only properties of LI, which are applicable in DCUCOPF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
LGEO	Length According to Map Coordinates	L
LD	Difference between actual pipeline length and geographic length	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of LI, which are applicable in ACOPF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
LGEO	Length According to Map Coordinates	L
LD	Difference between actual pipeline length and geographic length	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
BB	Positive sequence shunt susceptance in network per unit system	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of LI.
Parameter	Type	Description	UnitType
IMAX	Constraint	Maximum current. Minimum: 0.	CURR
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMAXREV	Constraint	Maximum active power in reverse flow direction. Minimum: 0.	PPOW
PMAXREVPRC	PenaltyPrice	Penalty price for maximum active power in reverse flow direction. Minimum: 0.	NRGPRC
SMAX	Constraint	Maximum apparent power. Minimum: 0.	SPOW

Summary for the events of LI, which are applicable in ACPF.
Parameter	Type	Description	UnitType
IMAX	Constraint	Maximum current. Minimum: 0.	CURR
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
SMAX	Constraint	Maximum apparent power. Minimum: 0.	SPOW

Summary for the events of LI, which are applicable in UACPF.
Parameter	Type	Description	UnitType
IMAX	Constraint	Maximum current. Minimum: 0.	CURR
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
SMAX	Constraint	Maximum apparent power. Minimum: 0.	SPOW

Summary for the events of LI, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMAXREV	Constraint	Maximum active power in reverse flow direction. Minimum: 0.	PPOW
PMAXREVPRC	PenaltyPrice	Penalty price for maximum active power in reverse flow direction. Minimum: 0.	NRGPRC

Summary for the events of LI, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
IMAX	Constraint	Maximum current. Minimum: 0.	CURR
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
SMAX	Constraint	Maximum apparent power. Minimum: 0.	SPOW

4.2. Transformer (TRF)

A branch in an electric network that represents a transformer. Note that for a transformer, FromNode is defined to be on the high-voltage end of the transformer and ToNode is defined to be on the low-voltage end of the transformer.

Summaries for the properties and events of TRF.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of TRF.
Extension	Description	UnitType
P	Active power flow through branch in DC-Scenarios	PPOW
IAPHASEA	Phase angle of current flowing through in the middle section of PI model of Phase A directed from FromNode to ToNode	ANGLE
IAPHASEB	Phase angle of current flowing through in the middle section of PI model of Phase B directed from FromNode to ToNode	ANGLE
IAPHASEC	Phase angle of current flowing through in the middle section of PI model of Phase C directed from FromNode to ToNode	ANGLE
PSHDW	Shadow price for maximum active power limit on the branch	NRGPRC
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current in the middle section of PI model directed from FromNode to ToNode	PU
IPHASEB	Magnitude of phase B current in the middle section of PI model directed from FromNode to ToNode	PU
IPHASEC	Magnitude of phase C current in the middle section of PI model directed from FromNode to ToNode	PU
STATEPHASEA	Current operating state of Phase A. Permitted states are ON or OFF
STATEPHASEB	Current operating state of Phase B. Permitted states are ON or OFF
STATEPHASEC	Current operating state of Phase C. Permitted states are ON or OFF
TAP	Resulting tap position	ND
TAPA	Resulting tap position for Phase A	ND
TAPB	Resulting tap position for Phase B	ND
TAPC	Resulting tap position for Phase C	ND

Summary for the base-result properties of TRF, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
TAP	Resulting tap position	ND

Summary for the base-result properties of TRF, which are applicable in UACPF.
Extension	Description	UnitType
IAPHASEA	Phase angle of current flowing through in the middle section of PI model of Phase A directed from FromNode to ToNode	ANGLE
IAPHASEB	Phase angle of current flowing through in the middle section of PI model of Phase B directed from FromNode to ToNode	ANGLE
IAPHASEC	Phase angle of current flowing through in the middle section of PI model of Phase C directed from FromNode to ToNode	ANGLE
IPHASEA	Magnitude of phase A current in the middle section of PI model directed from FromNode to ToNode	PU
IPHASEB	Magnitude of phase B current in the middle section of PI model directed from FromNode to ToNode	PU
IPHASEC	Magnitude of phase C current in the middle section of PI model directed from FromNode to ToNode	PU
STATEPHASEA	Current operating state of Phase A. Permitted states are ON or OFF
STATEPHASEB	Current operating state of Phase B. Permitted states are ON or OFF
STATEPHASEC	Current operating state of Phase C. Permitted states are ON or OFF
TAPA	Resulting tap position for Phase A	ND
TAPB	Resulting tap position for Phase B	ND
TAPC	Resulting tap position for Phase C	ND

Summary for the base-result properties of TRF, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Active power flow through branch in DC-Scenarios	PPOW
PSHDW	Shadow price for maximum active power limit on the branch	NRGPRC
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of TRF, which are applicable in ACOPF.
Extension	Description	UnitType
PSHDW	Shadow price for maximum active power limit on the branch	NRGPRC
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
TAP	Resulting tap position	ND

ALL
ACPF
ACOPF

Summary for the derived-event-value properties of TRF.
Extension	Description	UnitType
TAPR	Off-nominal tap ratio based on the calculated tap position	ND

Summary for the derived-event-value properties of TRF, which are applicable in ACPF.
Extension	Description	UnitType
TAPR	Off-nominal tap ratio based on the calculated tap position	ND

Summary for the derived-event-value properties of TRF, which are applicable in ACOPF.
Extension	Description	UnitType
TAPR	Off-nominal tap ratio based on the calculated tap position	ND

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of TRF.
Extension	Description	UnitType
PF	Total active power flow (+) leaving / (-) entering the FromNode	PPOW
PFPHASEA	Active power flow in Phase A (+) leaving / (-) entering the FromNode	PPOW
PFPHASEB	Active power flow in Phase B (+) leaving / (-) entering the FromNode	PPOW
PFPHASEC	Active power flow in Phase C (+) leaving / (-) entering the FromNode	PPOW
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLPPHASEA	Phase A active power loading calculated as a ratio between active power and maximum active power	PC
LLPPHASEB	Phase B active power loading calculated as a ratio between active power and maximum active power	PC
LLPPHASEC	Phase C active power loading calculated as a ratio between active power and maximum active power	PC
PL	Total active power loss in the branch	PPOW
PLPHASEA	Active power loss in Phase A	PPOW
PLPHASEB	Active power loss in Phase B	PPOW
PLPHASEC	Active power loss in Phase C	PPOW
PT	Total active power flow (+) leaving / (-) entering the ToNode	PPOW
PTPHASEA	Active power flow in Phase A (+) leaving / (-) entering the ToNode	PPOW
PTPHASEB	Active power flow in Phase B (+) leaving / (-) entering the ToNode	PPOW
PTPHASEC	Active power flow in Phase C (+) leaving / (-) entering the ToNode	PPOW
SF	Total apparent power passing through the branch, next to "from" node, of all the phases of parallel branches	SPOW
SFPHASEA	Apparent power passing through Phase A, next to "from" node	SPOW
SFPHASEB	Apparent power passing through Phase B, next to "from" node	SPOW
SFPHASEC	Apparent power passing through Phase C, next to "from" node	SPOW
LLS	Apparent power loading given as ratio between apparent power and maximum apparent power (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLSPHASEA	Phase A apparent power loading given as ratio between apparent power and maximum apparent power	PC
LLSPHASEB	Phase B apparent power loading given as ratio between apparent power and maximum apparent power	PC
LLSPHASEC	Phase C apparent power loading given as ratio between apparent power and maximum apparent power	PC
ST	Total apparent power passing through the branch, next to "to" node, of all the phases of parallel branches	SPOW
STPHASEA	Apparent power passing through Phase A, next to "to" node	SPOW
STPHASEB	Apparent power passing through Phase B, next to "to" node	SPOW
STPHASEC	Apparent power passing through Phase C, next to "to" node	SPOW
QLCF	Charging reactive power FromNode side	QPOW
QLCT	Charging reactive power ToNode side	QPOW
IA	Phase angle of the current in the middle part of PI-model directed from FromNode to ToNode	ANGLE
IAF	Phase angle of current flowing into FromNode	ANGLE
IAFPHASEA	Phase angle of phase A current leaving FromNode	ANGLE
IAFPHASEB	Phase angle of phase B current leaving FromNode	ANGLE
IAFPHASEC	Phase angle of phase C current leaving FromNode	ANGLE
IAT	Phase angle of current flowing into ToNode	ANGLE
IATPHASEA	Phase angle of phase A current leaving ToNode	ANGLE
IATPHASEB	Phase angle of phase B current leaving ToNode	ANGLE
IATPHASEC	Phase angle of phase C current leaving ToNode	ANGLE
LLI	Current loading given as ratio between current and maximum current (for unbalanced system, it returns the maximum loading among the three phases)	PC
IF	Magnitude of the current flowing into the branch from the FromNode assuming a balanced three-phase system	CURR
IFPHASEA	Magnitude of phase A current leaving FromNode	CURR
IFPHASEB	Magnitude of phase B current leaving FromNode	CURR
IFPHASEC	Magnitude of phase C current leaving FromNode	CURR
IT	Magnitude of the current flowing into the branch from the ToNode assuming a balanced three-phase system	CURR
ITPHASEA	Magnitude of phase A current leaving ToNode	CURR
ITPHASEB	Magnitude of phase B current leaving ToNode	CURR
ITPHASEC	Magnitude of phase C current leaving ToNode	CURR
IPU	Magnitude of the current in the middle part of PI-model in network per unit directed from FromNode to ToNode	PU
IAFNEUTRAL	Phase angle of the neutral current leaving the neutral point on the From side	ANGLE
IATNEUTRAL	Phase angle of the neutral current leaving the neutral point on the To side	ANGLE
IFNEUTRAL	Magnitude of the neutral current leaving the neutral point on the From side	CURR
ITNEUTRAL	Magnitude of the neutral current leaving the neutral point on the To side	CURR
QF	Total reactive power flow (+) leaving / (-) entering the FromNode	QPOW
QFPHASEA	Reactive power flow in Phase A (+) leaving / (-) entering the FromNode	QPOW
QFPHASEB	Reactive power flow in Phase B (+) leaving / (-) entering the FromNode	QPOW
QFPHASEC	Reactive power flow in Phase C (+) leaving / (-) entering the FromNode	QPOW
QL	Total reactive power consumption in the series part	QPOW
QLPHASEA	Reactive power consumption in the series part of Phase A	QPOW
QLPHASEB	Reactive power consumption in the series part of Phase B	QPOW
QLPHASEC	Reactive power consumption in the series part of Phase C	QPOW
QT	Total reactive power flow (+) leaving / (-) entering the ToNode	QPOW
QTPHASEA	Reactive power flow in Phase A (+) leaving / (-) entering the ToNode	QPOW
QTPHASEB	Reactive power flow in Phase B (+) leaving / (-) entering the ToNode	QPOW
QTPHASEC	Reactive power flow in Phase C (+) leaving / (-) entering the ToNode	QPOW
QTS	Reactive power flowing in to the ToNode in per unit of transformer base	PU
VREM	Voltage magnitude at the remote node in network per-unit. For LineDropComponsation control mode, it returns the ToNode voltage minus the line drop	PU
TAPRSET	Off-nominal tap ratio set point based on the tap position set point	ND
QLC	Total charging reactive power flowing through the shunt part	QPOW
QLCPHASEA	Total charging reactive power flowing through the shunt part of Phase A	QPOW
QLCPHASEB	Total charging reactive power flowing through the shunt part of Phase B	QPOW
QLCPHASEC	Total charging reactive power flowing through the shunt part of Phase C	QPOW
VAD	Voltage angle difference calculated as the difference between "ToNode" and "FromNode" voltage angles (VA)	ANGLE
VADPHASEA	Voltage angle difference on Phase A, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VADPHASEB	Voltage angle difference on Phase B, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VADPHASEC	Voltage angle difference on Phase C, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VAF	Voltage angle at FromNode	ANGLE
VAFPHASEA	Voltage angle at FromNode of Phase A	ANGLE
VAFPHASEB	Voltage angle at FromNode of Phase B	ANGLE
VAFPHASEC	Voltage angle at FromNode of Phase C	ANGLE
VAT	Voltage angle at ToNode	ANGLE
VATPHASEA	Voltage angle at ToNode of Phase A	ANGLE
VATPHASEB	Voltage angle at ToNode of Phase B	ANGLE
VATPHASEC	Voltage angle at ToNode of Phase C	ANGLE
VMD	Voltage magnitude of FromNode minus that of ToNode	VOLT
VMDPHASEA	Voltage magnitude of the phase A of FromNode minus that of ToNode	VOLT
VMDPHASEB	Voltage magnitude of the phase B of FromNode minus that of ToNode	VOLT
VMDPHASEC	Voltage magnitude of the phase C of FromNode minus that of ToNode	VOLT
VMF	Voltage magnitude at FromNode (for UACPF, the average line-to-line voltage at the FromNode is taken)	VOLT
VMFPHASEA	Voltage magnitude at FromNode of Phase A	VOLT
VMFPHASEB	Voltage magnitude at FromNode of Phase B	VOLT
VMFPHASEC	Voltage magnitude at FromNode of Phase C	VOLT
VMR	Voltage magnitude ratio, ratio between ToNode and FromNode voltage magnitudes (for UACPF, the ratio between the average line-to-line voltages at the two sides is taken)	ND
VMRPHASEA	Phase A voltage magnitude ratio between ToNode and FromNode voltage magnitudes	ND
VMRPHASEB	Phase B voltage magnitude ratio between ToNode and FromNode voltage magnitudes	ND
VMRPHASEC	Phase C voltage magnitude ratio between ToNode and FromNode voltage magnitudes of Phase C	ND
VMT	Voltage magnitude ToNode (for UACPF, the average line-to-line voltage at the ToNode is taken)	VOLT
VMTPHASEA	Voltage magnitude at ToNode of Phase A	VOLT
VMTPHASEB	Voltage magnitude at ToNode of Phase B	VOLT
VMTPHASEC	Voltage magnitude at ToNode of Phase C	VOLT

Summary for the derived-result properties of TRF, which are applicable in ACPF.
Extension	Description	UnitType
PF	Total active power flow (+) leaving / (-) entering the FromNode	PPOW
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
PL	Total active power loss in the branch	PPOW
PT	Total active power flow (+) leaving / (-) entering the ToNode	PPOW
SF	Total apparent power passing through the branch, next to "from" node, of all the phases of parallel branches	SPOW
LLS	Apparent power loading given as ratio between apparent power and maximum apparent power (for unbalanced system, it returns the maximum loading among the three phases)	PC
ST	Total apparent power passing through the branch, next to "to" node, of all the phases of parallel branches	SPOW
QLCF	Charging reactive power FromNode side	QPOW
QLCT	Charging reactive power ToNode side	QPOW
IA	Phase angle of the current in the middle part of PI-model directed from FromNode to ToNode	ANGLE
IAF	Phase angle of current flowing into FromNode	ANGLE
IAT	Phase angle of current flowing into ToNode	ANGLE
LLI	Current loading given as ratio between current and maximum current (for unbalanced system, it returns the maximum loading among the three phases)	PC
IF	Magnitude of the current flowing into the branch from the FromNode assuming a balanced three-phase system	CURR
IT	Magnitude of the current flowing into the branch from the ToNode assuming a balanced three-phase system	CURR
IPU	Magnitude of the current in the middle part of PI-model in network per unit directed from FromNode to ToNode	PU
QF	Total reactive power flow (+) leaving / (-) entering the FromNode	QPOW
QL	Total reactive power consumption in the series part	QPOW
QT	Total reactive power flow (+) leaving / (-) entering the ToNode	QPOW
QTS	Reactive power flowing in to the ToNode in per unit of transformer base	PU
VREM	Voltage magnitude at the remote node in network per-unit. For LineDropComponsation control mode, it returns the ToNode voltage minus the line drop	PU
TAPRSET	Off-nominal tap ratio set point based on the tap position set point	ND
QLC	Total charging reactive power flowing through the shunt part	QPOW
VAD	Voltage angle difference calculated as the difference between "ToNode" and "FromNode" voltage angles (VA)	ANGLE
VAF	Voltage angle at FromNode	ANGLE
VAT	Voltage angle at ToNode	ANGLE
VMD	Voltage magnitude of FromNode minus that of ToNode	VOLT
VMF	Voltage magnitude at FromNode (for UACPF, the average line-to-line voltage at the FromNode is taken)	VOLT
VMR	Voltage magnitude ratio, ratio between ToNode and FromNode voltage magnitudes (for UACPF, the ratio between the average line-to-line voltages at the two sides is taken)	ND
VMT	Voltage magnitude ToNode (for UACPF, the average line-to-line voltage at the ToNode is taken)	VOLT

Summary for the derived-result properties of TRF, which are applicable in UACPF.
Extension	Description	UnitType
PF	Total active power flow (+) leaving / (-) entering the FromNode	PPOW
PFPHASEA	Active power flow in Phase A (+) leaving / (-) entering the FromNode	PPOW
PFPHASEB	Active power flow in Phase B (+) leaving / (-) entering the FromNode	PPOW
PFPHASEC	Active power flow in Phase C (+) leaving / (-) entering the FromNode	PPOW
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLPPHASEA	Phase A active power loading calculated as a ratio between active power and maximum active power	PC
LLPPHASEB	Phase B active power loading calculated as a ratio between active power and maximum active power	PC
LLPPHASEC	Phase C active power loading calculated as a ratio between active power and maximum active power	PC
PL	Total active power loss in the branch	PPOW
PLPHASEA	Active power loss in Phase A	PPOW
PLPHASEB	Active power loss in Phase B	PPOW
PLPHASEC	Active power loss in Phase C	PPOW
PT	Total active power flow (+) leaving / (-) entering the ToNode	PPOW
PTPHASEA	Active power flow in Phase A (+) leaving / (-) entering the ToNode	PPOW
PTPHASEB	Active power flow in Phase B (+) leaving / (-) entering the ToNode	PPOW
PTPHASEC	Active power flow in Phase C (+) leaving / (-) entering the ToNode	PPOW
SF	Total apparent power passing through the branch, next to "from" node, of all the phases of parallel branches	SPOW
SFPHASEA	Apparent power passing through Phase A, next to "from" node	SPOW
SFPHASEB	Apparent power passing through Phase B, next to "from" node	SPOW
SFPHASEC	Apparent power passing through Phase C, next to "from" node	SPOW
LLS	Apparent power loading given as ratio between apparent power and maximum apparent power (for unbalanced system, it returns the maximum loading among the three phases)	PC
LLSPHASEA	Phase A apparent power loading given as ratio between apparent power and maximum apparent power	PC
LLSPHASEB	Phase B apparent power loading given as ratio between apparent power and maximum apparent power	PC
LLSPHASEC	Phase C apparent power loading given as ratio between apparent power and maximum apparent power	PC
ST	Total apparent power passing through the branch, next to "to" node, of all the phases of parallel branches	SPOW
STPHASEA	Apparent power passing through Phase A, next to "to" node	SPOW
STPHASEB	Apparent power passing through Phase B, next to "to" node	SPOW
STPHASEC	Apparent power passing through Phase C, next to "to" node	SPOW
IAFPHASEA	Phase angle of phase A current leaving FromNode	ANGLE
IAFPHASEB	Phase angle of phase B current leaving FromNode	ANGLE
IAFPHASEC	Phase angle of phase C current leaving FromNode	ANGLE
IATPHASEA	Phase angle of phase A current leaving ToNode	ANGLE
IATPHASEB	Phase angle of phase B current leaving ToNode	ANGLE
IATPHASEC	Phase angle of phase C current leaving ToNode	ANGLE
LLI	Current loading given as ratio between current and maximum current (for unbalanced system, it returns the maximum loading among the three phases)	PC
IFPHASEA	Magnitude of phase A current leaving FromNode	CURR
IFPHASEB	Magnitude of phase B current leaving FromNode	CURR
IFPHASEC	Magnitude of phase C current leaving FromNode	CURR
ITPHASEA	Magnitude of phase A current leaving ToNode	CURR
ITPHASEB	Magnitude of phase B current leaving ToNode	CURR
ITPHASEC	Magnitude of phase C current leaving ToNode	CURR
IAFNEUTRAL	Phase angle of the neutral current leaving the neutral point on the From side	ANGLE
IATNEUTRAL	Phase angle of the neutral current leaving the neutral point on the To side	ANGLE
IFNEUTRAL	Magnitude of the neutral current leaving the neutral point on the From side	CURR
ITNEUTRAL	Magnitude of the neutral current leaving the neutral point on the To side	CURR
QF	Total reactive power flow (+) leaving / (-) entering the FromNode	QPOW
QFPHASEA	Reactive power flow in Phase A (+) leaving / (-) entering the FromNode	QPOW
QFPHASEB	Reactive power flow in Phase B (+) leaving / (-) entering the FromNode	QPOW
QFPHASEC	Reactive power flow in Phase C (+) leaving / (-) entering the FromNode	QPOW
QL	Total reactive power consumption in the series part	QPOW
QLPHASEA	Reactive power consumption in the series part of Phase A	QPOW
QLPHASEB	Reactive power consumption in the series part of Phase B	QPOW
QLPHASEC	Reactive power consumption in the series part of Phase C	QPOW
QT	Total reactive power flow (+) leaving / (-) entering the ToNode	QPOW
QTPHASEA	Reactive power flow in Phase A (+) leaving / (-) entering the ToNode	QPOW
QTPHASEB	Reactive power flow in Phase B (+) leaving / (-) entering the ToNode	QPOW
QTPHASEC	Reactive power flow in Phase C (+) leaving / (-) entering the ToNode	QPOW
QTS	Reactive power flowing in to the ToNode in per unit of transformer base	PU
VREM	Voltage magnitude at the remote node in network per-unit. For LineDropComponsation control mode, it returns the ToNode voltage minus the line drop	PU
TAPRSET	Off-nominal tap ratio set point based on the tap position set point	ND
QLC	Total charging reactive power flowing through the shunt part	QPOW
QLCPHASEA	Total charging reactive power flowing through the shunt part of Phase A	QPOW
QLCPHASEB	Total charging reactive power flowing through the shunt part of Phase B	QPOW
QLCPHASEC	Total charging reactive power flowing through the shunt part of Phase C	QPOW
VADPHASEA	Voltage angle difference on Phase A, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VADPHASEB	Voltage angle difference on Phase B, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VADPHASEC	Voltage angle difference on Phase C, calculated as the difference between ToNode and FromNode voltage angles (VA)	ANGLE
VAFPHASEA	Voltage angle at FromNode of Phase A	ANGLE
VAFPHASEB	Voltage angle at FromNode of Phase B	ANGLE
VAFPHASEC	Voltage angle at FromNode of Phase C	ANGLE
VATPHASEA	Voltage angle at ToNode of Phase A	ANGLE
VATPHASEB	Voltage angle at ToNode of Phase B	ANGLE
VATPHASEC	Voltage angle at ToNode of Phase C	ANGLE
VMDPHASEA	Voltage magnitude of the phase A of FromNode minus that of ToNode	VOLT
VMDPHASEB	Voltage magnitude of the phase B of FromNode minus that of ToNode	VOLT
VMDPHASEC	Voltage magnitude of the phase C of FromNode minus that of ToNode	VOLT
VMF	Voltage magnitude at FromNode (for UACPF, the average line-to-line voltage at the FromNode is taken)	VOLT
VMFPHASEA	Voltage magnitude at FromNode of Phase A	VOLT
VMFPHASEB	Voltage magnitude at FromNode of Phase B	VOLT
VMFPHASEC	Voltage magnitude at FromNode of Phase C	VOLT
VMR	Voltage magnitude ratio, ratio between ToNode and FromNode voltage magnitudes (for UACPF, the ratio between the average line-to-line voltages at the two sides is taken)	ND
VMRPHASEA	Phase A voltage magnitude ratio between ToNode and FromNode voltage magnitudes	ND
VMRPHASEB	Phase B voltage magnitude ratio between ToNode and FromNode voltage magnitudes	ND
VMRPHASEC	Phase C voltage magnitude ratio between ToNode and FromNode voltage magnitudes of Phase C	ND
VMT	Voltage magnitude ToNode (for UACPF, the average line-to-line voltage at the ToNode is taken)	VOLT
VMTPHASEA	Voltage magnitude at ToNode of Phase A	VOLT
VMTPHASEB	Voltage magnitude at ToNode of Phase B	VOLT
VMTPHASEC	Voltage magnitude at ToNode of Phase C	VOLT

Summary for the derived-result properties of TRF, which are applicable in DCUCOPF.
Extension	Description	UnitType
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
PL	Total active power loss in the branch	PPOW
VAD	Voltage angle difference calculated as the difference between "ToNode" and "FromNode" voltage angles (VA)	ANGLE
VAF	Voltage angle at FromNode	ANGLE
VAT	Voltage angle at ToNode	ANGLE

Summary for the derived-result properties of TRF, which are applicable in ACOPF.
Extension	Description	UnitType
PF	Total active power flow (+) leaving / (-) entering the FromNode	PPOW
LLP	Active power loading calculated as a ratio between active power (P) and maximum active power (PMAX). PMAX = PMAXDEF if no PMAX event defined (for unbalanced system, it returns the maximum loading among the three phases)	PC
PL	Total active power loss in the branch	PPOW
PT	Total active power flow (+) leaving / (-) entering the ToNode	PPOW
SF	Total apparent power passing through the branch, next to "from" node, of all the phases of parallel branches	SPOW
LLS	Apparent power loading given as ratio between apparent power and maximum apparent power (for unbalanced system, it returns the maximum loading among the three phases)	PC
ST	Total apparent power passing through the branch, next to "to" node, of all the phases of parallel branches	SPOW
QLCF	Charging reactive power FromNode side	QPOW
QLCT	Charging reactive power ToNode side	QPOW
IA	Phase angle of the current in the middle part of PI-model directed from FromNode to ToNode	ANGLE
IAF	Phase angle of current flowing into FromNode	ANGLE
IAT	Phase angle of current flowing into ToNode	ANGLE
LLI	Current loading given as ratio between current and maximum current (for unbalanced system, it returns the maximum loading among the three phases)	PC
IF	Magnitude of the current flowing into the branch from the FromNode assuming a balanced three-phase system	CURR
IT	Magnitude of the current flowing into the branch from the ToNode assuming a balanced three-phase system	CURR
IPU	Magnitude of the current in the middle part of PI-model in network per unit directed from FromNode to ToNode	PU
QF	Total reactive power flow (+) leaving / (-) entering the FromNode	QPOW
QL	Total reactive power consumption in the series part	QPOW
QT	Total reactive power flow (+) leaving / (-) entering the ToNode	QPOW
TAPRSET	Off-nominal tap ratio set point based on the tap position set point	ND
QLC	Total charging reactive power flowing through the shunt part	QPOW
VAD	Voltage angle difference calculated as the difference between "ToNode" and "FromNode" voltage angles (VA)	ANGLE
VAF	Voltage angle at FromNode	ANGLE
VAT	Voltage angle at ToNode	ANGLE
VMD	Voltage magnitude of FromNode minus that of ToNode	VOLT
VMF	Voltage magnitude at FromNode (for UACPF, the average line-to-line voltage at the FromNode is taken)	VOLT
VMR	Voltage magnitude ratio, ratio between ToNode and FromNode voltage magnitudes (for UACPF, the ratio between the average line-to-line voltages at the two sides is taken)	ND
VMT	Voltage magnitude ToNode (for UACPF, the average line-to-line voltage at the ToNode is taken)	VOLT

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of TRF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power flow (PMAX). This property is the default value for the PMAXPRC property if no PMAXPRC event is defined in a scenario. Penalty is calculated as (P-PMAX) * PMAXPRC	NRGPRC
SMAXDEF	Default maximum apparent power	SPOW
IMAXDEF	Default maximum current magnitude in each phase of a balanced three-phase branch	CURR
PMAXREVDEF	Default maximum active power in the negative flow direction. It constrains the active power flow only in the negative flow direction, i.e. in the "ToNode" to "FromNode" flow direction. This property is the default value for the PMAXREV property if no PMAXREV event is defined in a scenario. It is only considered if a REVON event is defined for the electric network	PPOW
PMAXREVPRCDEF	Default penalty price for exceeding the maximum active power in negative flow direction (PMAXREV), i.e. "ToNode" to "FromNode" flow direction. This property is the default value for the PMAXREVPRC property if no PMAXREVPRC event is defined in a scenario. Penalty is calculated as (P-PMAXREV) * PMAXREVPRC	NRGPRC
PHISETDEF	Default value for phase shift angle	ANGLE
QSETDEF	Reactive power set point in per unit of transformer base, applied only for ReactivePower control mode	PU
TAPSETDEF	Default value for tap position	ND
VMSETDEF	Default voltage magnitude set point in per unit of network base, applied only for Voltage and LineDropCompensation control modes	PU

Summary for the event-default properties of TRF, which are applicable in ACPF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
SMAXDEF	Default maximum apparent power	SPOW
IMAXDEF	Default maximum current magnitude in each phase of a balanced three-phase branch	CURR
PHISETDEF	Default value for phase shift angle	ANGLE
QSETDEF	Reactive power set point in per unit of transformer base, applied only for ReactivePower control mode	PU
TAPSETDEF	Default value for tap position	ND
VMSETDEF	Default voltage magnitude set point in per unit of network base, applied only for Voltage and LineDropCompensation control modes	PU

Summary for the event-default properties of TRF, which are applicable in UACPF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
SMAXDEF	Default maximum apparent power	SPOW
IMAXDEF	Default maximum current magnitude in each phase of a balanced three-phase branch	CURR
PHISETDEF	Default value for phase shift angle	ANGLE
QSETDEF	Reactive power set point in per unit of transformer base, applied only for ReactivePower control mode	PU
TAPSETDEF	Default value for tap position	ND
VMSETDEF	Default voltage magnitude set point in per unit of network base, applied only for Voltage and LineDropCompensation control modes	PU

Summary for the event-default properties of TRF, which are applicable in DCUCOPF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power flow (PMAX). This property is the default value for the PMAXPRC property if no PMAXPRC event is defined in a scenario. Penalty is calculated as (P-PMAX) * PMAXPRC	NRGPRC
PMAXREVDEF	Default maximum active power in the negative flow direction. It constrains the active power flow only in the negative flow direction, i.e. in the "ToNode" to "FromNode" flow direction. This property is the default value for the PMAXREV property if no PMAXREV event is defined in a scenario. It is only considered if a REVON event is defined for the electric network	PPOW
PMAXREVPRCDEF	Default penalty price for exceeding the maximum active power in negative flow direction (PMAXREV), i.e. "ToNode" to "FromNode" flow direction. This property is the default value for the PMAXREVPRC property if no PMAXREVPRC event is defined in a scenario. Penalty is calculated as (P-PMAXREV) * PMAXREVPRC	NRGPRC

Summary for the event-default properties of TRF, which are applicable in ACOPF.
Extension	Description	UnitType
PMAXDEF	Default maximum active power. It constrains the active power flow only in the positive flow direction, i.e. in the "FromNode" to "ToNode" flow direction, if a REVON event is defined for the electric network, otherwise both flow directions are constrained by PMAX. This property is the default value for the PMAX property if no PMAX event is defined in a scenario	PPOW
SMAXDEF	Default maximum apparent power	SPOW
IMAXDEF	Default maximum current magnitude in each phase of a balanced three-phase branch	CURR
PHISETDEF	Default value for phase shift angle	ANGLE
TAPSETDEF	Default value for tap position	ND

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of TRF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
PMAXPRC	Penalty price for maximum active power flow through the branch. Equal to PMAXPRCDEF property unless a PMAXPRC event is defined for the scenario. Penalty is calculated as (P-PMAX) * PMAXPRC	NRGPRC
SMAX	Maximum apparent power	SPOW
IMAX	Maximum current magnitude in each phase of a balanced three-phase branch	CURR
PMAXREVPRC	Penalty price for maximum active power in reverse branch flow direction (PMAXREV). Equal to PMAXREVPRCDEF property unless a PMAXREVPRC event is defined for the scenario. Penalty is calculated as (P-PMAXREV) * PMAXREVPRC	NRGPRC
PMAXREV	Maximum active power in reverse branch flow direction (positive number, can be greater than PMAX, only considered if a REVON event is defined for the electric network). Equal to PMAXREVDEF property unless a PMAXREV event is defined for the scenario	PPOW
PHISET	Phase shift angle set point	ANGLE
QSET	Reactive power set point in per unit of transformer base, applied only for ReactivePower control mode	PU
TAPSET	Tap position set by event	ND
VMSET	Voltage magnitude set point in per unit of network base, applied only for Voltage and LineDropCompensation control modes	PU

Summary for the event-value properties of TRF, which are applicable in ACPF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
SMAX	Maximum apparent power	SPOW
IMAX	Maximum current magnitude in each phase of a balanced three-phase branch	CURR
PHISET	Phase shift angle set point	ANGLE
QSET	Reactive power set point in per unit of transformer base, applied only for ReactivePower control mode	PU
TAPSET	Tap position set by event	ND
VMSET	Voltage magnitude set point in per unit of network base, applied only for Voltage and LineDropCompensation control modes	PU

Summary for the event-value properties of TRF, which are applicable in UACPF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
SMAX	Maximum apparent power	SPOW
IMAX	Maximum current magnitude in each phase of a balanced three-phase branch	CURR
PHISET	Phase shift angle set point	ANGLE
QSET	Reactive power set point in per unit of transformer base, applied only for ReactivePower control mode	PU
TAPSET	Tap position set by event	ND
VMSET	Voltage magnitude set point in per unit of network base, applied only for Voltage and LineDropCompensation control modes	PU

Summary for the event-value properties of TRF, which are applicable in DCUCOPF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
PMAXPRC	Penalty price for maximum active power flow through the branch. Equal to PMAXPRCDEF property unless a PMAXPRC event is defined for the scenario. Penalty is calculated as (P-PMAX) * PMAXPRC	NRGPRC
PMAXREVPRC	Penalty price for maximum active power in reverse branch flow direction (PMAXREV). Equal to PMAXREVPRCDEF property unless a PMAXREVPRC event is defined for the scenario. Penalty is calculated as (P-PMAXREV) * PMAXREVPRC	NRGPRC
PMAXREV	Maximum active power in reverse branch flow direction (positive number, can be greater than PMAX, only considered if a REVON event is defined for the electric network). Equal to PMAXREVDEF property unless a PMAXREV event is defined for the scenario	PPOW

Summary for the event-value properties of TRF, which are applicable in ACOPF.
Extension	Description	UnitType
PMAX	Maximum active power flow through the branch. Equal to PMAXDEF property unless a PMAX event is defined for the scenario	PPOW
SMAX	Maximum apparent power	SPOW
IMAX	Maximum current magnitude in each phase of a balanced three-phase branch	CURR
PHISET	Phase shift angle set point	ANGLE
TAPSET	Tap position set by event	ND
VMSET	Voltage magnitude set point in per unit of network base, applied only for Voltage and LineDropCompensation control modes	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of TRF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the test-related properties of a transformer are used
CTRLMODE	Control mode of the transformer, valid inputs are TapSet, Voltage, LineDropCompensation, or ReactivePower. Default is TapSet mode. Any TapSet event will override other control modes.
PCU	Copper (full load) loss, measured in the short circuit test in MW. Not applied if "CalcImp" is false	PPOW
D	Deadband, the full distance (ball) around the set point for which the tap keeps the vale from the previous time step. Value expressed in per unit at the base voltage of the the node under control for Voltage or LineDropCompensation control mode; or in per unit of the transformer rated apparent power for ReactivePower control mode	PU
GGDEF	Positive sequence shunt conductance in branch per unit system. Used if "CalcImp" is false	PU
XXDEF	Positive sequence series reactance in branch per unit system. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
BBDEF	Positive sequence shunt susceptance in network per unit system. Used if "CalcImp" is false. Must be non-positive for electric transformer, because the shunt is inductive	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
FROMRATEDV	Rated line-to-line voltage magnitude on the FromNode side, assuming balanced three-phase object. Used in transformer per unit system	VOLT
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
PFE	Iron (core) loss, measured in the open‑circuit test in MW. Not used if "CalcImp" is false	PPOW
XDROP	Line drop reactance in per unit at the transformer base, applied only for the LineDropCompensation control mode	PU
RDROP	Line drop resistance in per unit at the transformer base, applied only for the LineDropCompensation control mode	PU
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
IOL	Open loop (no‑load current), measured in the open‑circuit test and expressed as a percentage of the rated current of the transformer. Not used if "CalcImp" is false	PC
PHASESINUSE	Identifies which phases of the transformer are connected, valid values are A, B, C, or ABC. All of them are assumed to be connected to a neutral with zero impedance.
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RemoteName	Name of electric remote node whose voltage is controlled by this transformer
VSC	Short circuit voltage, measured in the short circuit test and expressed as a percentage of the rated voltage of the transformer. Not used if "CalcImp" is false	PC
SubName	Sub the branch belongs to
TAPMAX	Maximum value of available tap positions	ND
TAPMIN	Minimum value of available tap positions	ND
TAPN	Tap position where the off-nominal ratio (ONR) is 1	ND
TAPSide	Indicates which side (FromNode or ToNode) of the transformer the tap is installed on. Valid inputs are "From" or "To"
TAPSTEP	Indicates how much off-nominal tap ratio changes [%] when tap position changes by one step	PC
ToName	Name of ToNode
TORATEDV	Rated line-to-line voltage magnitude on the ToNode side, assuming balanced three-phase object. Used in transformer per unit system	VOLT
TRFModel	Which equivalent circuit (T or PI) is used for branch admittance matrix
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of TRF, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the test-related properties of a transformer are used
CTRLMODE	Control mode of the transformer, valid inputs are TapSet, Voltage, LineDropCompensation, or ReactivePower. Default is TapSet mode. Any TapSet event will override other control modes.
PCU	Copper (full load) loss, measured in the short circuit test in MW. Not applied if "CalcImp" is false	PPOW
D	Deadband, the full distance (ball) around the set point for which the tap keeps the vale from the previous time step. Value expressed in per unit at the base voltage of the the node under control for Voltage or LineDropCompensation control mode; or in per unit of the transformer rated apparent power for ReactivePower control mode	PU
GGDEF	Positive sequence shunt conductance in branch per unit system. Used if "CalcImp" is false	PU
XXDEF	Positive sequence series reactance in branch per unit system. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
BBDEF	Positive sequence shunt susceptance in network per unit system. Used if "CalcImp" is false. Must be non-positive for electric transformer, because the shunt is inductive	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
FROMRATEDV	Rated line-to-line voltage magnitude on the FromNode side, assuming balanced three-phase object. Used in transformer per unit system	VOLT
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
PFE	Iron (core) loss, measured in the open‑circuit test in MW. Not used if "CalcImp" is false	PPOW
XDROP	Line drop reactance in per unit at the transformer base, applied only for the LineDropCompensation control mode	PU
RDROP	Line drop resistance in per unit at the transformer base, applied only for the LineDropCompensation control mode	PU
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
IOL	Open loop (no‑load current), measured in the open‑circuit test and expressed as a percentage of the rated current of the transformer. Not used if "CalcImp" is false	PC
PHASESINUSE	Identifies which phases of the transformer are connected, valid values are A, B, C, or ABC. All of them are assumed to be connected to a neutral with zero impedance.
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RemoteName	Name of electric remote node whose voltage is controlled by this transformer
VSC	Short circuit voltage, measured in the short circuit test and expressed as a percentage of the rated voltage of the transformer. Not used if "CalcImp" is false	PC
SubName	Sub the branch belongs to
TAPMAX	Maximum value of available tap positions	ND
TAPMIN	Minimum value of available tap positions	ND
TAPN	Tap position where the off-nominal ratio (ONR) is 1	ND
TAPSide	Indicates which side (FromNode or ToNode) of the transformer the tap is installed on. Valid inputs are "From" or "To"
TAPSTEP	Indicates how much off-nominal tap ratio changes [%] when tap position changes by one step	PC
ToName	Name of ToNode
TORATEDV	Rated line-to-line voltage magnitude on the ToNode side, assuming balanced three-phase object. Used in transformer per unit system	VOLT
TRFModel	Which equivalent circuit (T or PI) is used for branch admittance matrix
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of TRF, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the test-related properties of a transformer are used
CTRLMODE	Control mode of the transformer, valid inputs are TapSet, Voltage, LineDropCompensation, or ReactivePower. Default is TapSet mode. Any TapSet event will override other control modes.
PCU	Copper (full load) loss, measured in the short circuit test in MW. Not applied if "CalcImp" is false	PPOW
D	Deadband, the full distance (ball) around the set point for which the tap keeps the vale from the previous time step. Value expressed in per unit at the base voltage of the the node under control for Voltage or LineDropCompensation control mode; or in per unit of the transformer rated apparent power for ReactivePower control mode	PU
GGDEF	Positive sequence shunt conductance in branch per unit system. Used if "CalcImp" is false	PU
XXDEF	Positive sequence series reactance in branch per unit system. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
BBDEF	Positive sequence shunt susceptance in network per unit system. Used if "CalcImp" is false. Must be non-positive for electric transformer, because the shunt is inductive	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
FROMRATEDV	Rated line-to-line voltage magnitude on the FromNode side, assuming balanced three-phase object. Used in transformer per unit system	VOLT
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
PFE	Iron (core) loss, measured in the open‑circuit test in MW. Not used if "CalcImp" is false	PPOW
XDROP	Line drop reactance in per unit at the transformer base, applied only for the LineDropCompensation control mode	PU
RDROP	Line drop resistance in per unit at the transformer base, applied only for the LineDropCompensation control mode	PU
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
IOL	Open loop (no‑load current), measured in the open‑circuit test and expressed as a percentage of the rated current of the transformer. Not used if "CalcImp" is false	PC
PHASESINUSE	Identifies which phases of the transformer are connected, valid values are A, B, C, or ABC. All of them are assumed to be connected to a neutral with zero impedance.
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RemoteName	Name of electric remote node whose voltage is controlled by this transformer
VSC	Short circuit voltage, measured in the short circuit test and expressed as a percentage of the rated voltage of the transformer. Not used if "CalcImp" is false	PC
SubName	Sub the branch belongs to
TAPMAX	Maximum value of available tap positions	ND
TAPMIN	Minimum value of available tap positions	ND
TAPN	Tap position where the off-nominal ratio (ONR) is 1	ND
TAPSide	Indicates which side (FromNode or ToNode) of the transformer the tap is installed on. Valid inputs are "From" or "To"
TAPSTEP	Indicates how much off-nominal tap ratio changes [%] when tap position changes by one step	PC
ToName	Name of ToNode
TORATEDV	Rated line-to-line voltage magnitude on the ToNode side, assuming balanced three-phase object. Used in transformer per unit system	VOLT
TRFModel	Which equivalent circuit (T or PI) is used for branch admittance matrix
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of TRF, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the test-related properties of a transformer are used
XXDEF	Positive sequence series reactance in branch per unit system. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
SubName	Sub the branch belongs to
ToName	Name of ToNode
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of TRF, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CalcImp	Indicates how the network per unit impedances are calculated. If CalcImp is false, the branch per unit values are used for the calculation. If true, the test-related properties of a transformer are used
PCU	Copper (full load) loss, measured in the short circuit test in MW. Not applied if "CalcImp" is false	PPOW
GGDEF	Positive sequence shunt conductance in branch per unit system. Used if "CalcImp" is false	PU
XXDEF	Positive sequence series reactance in branch per unit system. Used if "CalcImp" is false.	PU
RRDEF	Positive sequence series resistance in branch per unit system. Defined to be non-negative. Used if "CalcImp" is false.	PU
BBDEF	Positive sequence shunt susceptance in network per unit system. Used if "CalcImp" is false. Must be non-positive for electric transformer, because the shunt is inductive	PU
DrawLine	If true, element will be drawn as a straight line and internal points will be neglected	NO
FromName	Name of FromNode
FROMRATEDV	Rated line-to-line voltage magnitude on the FromNode side, assuming balanced three-phase object. Used in transformer per unit system	VOLT
N	Scaling factor for impedances. The series impedance will be divided by this value, and the shunt admittance will be multiplied by this value. Not used if "CalcImp" is false	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
PFE	Iron (core) loss, measured in the open‑circuit test in MW. Not used if "CalcImp" is false	PPOW
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
IOL	Open loop (no‑load current), measured in the open‑circuit test and expressed as a percentage of the rated current of the transformer. Not used if "CalcImp" is false	PC
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
VSC	Short circuit voltage, measured in the short circuit test and expressed as a percentage of the rated voltage of the transformer. Not used if "CalcImp" is false	PC
SubName	Sub the branch belongs to
TAPMAX	Maximum value of available tap positions	ND
TAPMIN	Minimum value of available tap positions	ND
TAPN	Tap position where the off-nominal ratio (ONR) is 1	ND
TAPSide	Indicates which side (FromNode or ToNode) of the transformer the tap is installed on. Valid inputs are "From" or "To"
TAPSTEP	Indicates how much off-nominal tap ratio changes [%] when tap position changes by one step	PC
ToName	Name of ToNode
TORATEDV	Rated line-to-line voltage magnitude on the ToNode side, assuming balanced three-phase object. Used in transformer per unit system	VOLT
TRFModel	Which equivalent circuit (T or PI) is used for branch admittance matrix
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of TRF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
TAPRDEF	Default value for magnitude of off-nominal tap ratio [pu/pu] based on "TapSetDef"	ND
LGEO	Length According to Map Coordinates	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
GG	Positive sequence shunt conductance in network per unit system	PU
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
BB	Positive sequence shunt susceptance in network per unit system	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of TRF, which are applicable in ACPF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
TAPRDEF	Default value for magnitude of off-nominal tap ratio [pu/pu] based on "TapSetDef"	ND
LGEO	Length According to Map Coordinates	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
GG	Positive sequence shunt conductance in network per unit system	PU
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
BB	Positive sequence shunt susceptance in network per unit system	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of TRF, which are applicable in UACPF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
LGEO	Length According to Map Coordinates	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
GG	Positive sequence shunt conductance in network per unit system	PU
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
BB	Positive sequence shunt susceptance in network per unit system	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of TRF, which are applicable in DCUCOPF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
LGEO	Length According to Map Coordinates	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of TRF, which are applicable in ACOPF.
Extension	Description	UnitType
FromBaseV	Base voltage at the "FromNode" of the electric branch (FromBaseV)	VOLT
ToBaseV	Base voltage at the "ToNode" of the electric branch (ToBaseV)	VOLT
TAPRDEF	Default value for magnitude of off-nominal tap ratio [pu/pu] based on "TapSetDef"	ND
LGEO	Length According to Map Coordinates	L
NetType	Network Type
ID	Object Identification
ObjType	Object Type
GG	Positive sequence shunt conductance in network per unit system	PU
XX	Positive sequence series reactance in network per unit system.	PU
RR	Positive sequence series resistance in network per unit system.	PU
BB	Positive sequence shunt susceptance in network per unit system	PU
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of TRF.
Parameter	Type	Description	UnitType
IMAX	Constraint	Maximum current. Minimum: 0.	CURR
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PHISET	SetPoint	Phase shift set point. Minimum: -360. Maximum: 360.	ANGLE
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMAXREV	Constraint	Maximum active power in reverse flow direction. Minimum: 0.	PPOW
PMAXREVPRC	PenaltyPrice	Penalty price for maximum active power in reverse flow direction. Minimum: 0.	NRGPRC
QSET	SetPoint	Total reactive power set point. Minimum: -1.2. Maximum: 1.2.	PU
SMAX	Constraint	Maximum apparent power. Minimum: 0.	SPOW
TAPSET	SetPoint	Tap position set point.	ND
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of TRF, which are applicable in ACPF.
Parameter	Type	Description	UnitType
IMAX	Constraint	Maximum current. Minimum: 0.	CURR
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PHISET	SetPoint	Phase shift set point. Minimum: -360. Maximum: 360.	ANGLE
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
QSET	SetPoint	Total reactive power set point. Minimum: -1.2. Maximum: 1.2.	PU
SMAX	Constraint	Maximum apparent power. Minimum: 0.	SPOW
TAPSET	SetPoint	Tap position set point.	ND
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of TRF, which are applicable in UACPF.
Parameter	Type	Description	UnitType
IMAX	Constraint	Maximum current. Minimum: 0.	CURR
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PHISET	SetPoint	Phase shift set point. Minimum: -360. Maximum: 360.	ANGLE
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
QSET	SetPoint	Total reactive power set point. Minimum: -1.2. Maximum: 1.2.	PU
SMAX	Constraint	Maximum apparent power. Minimum: 0.	SPOW
TAPSET	SetPoint	Tap position set point.	ND
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of TRF, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMAXREV	Constraint	Maximum active power in reverse flow direction. Minimum: 0.	PPOW
PMAXREVPRC	PenaltyPrice	Penalty price for maximum active power in reverse flow direction. Minimum: 0.	NRGPRC

Summary for the events of TRF, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
IMAX	Constraint	Maximum current. Minimum: 0.	CURR
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PHISET	SetPoint	Phase shift set point. Minimum: -360. Maximum: 360.	ANGLE
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
SMAX	Constraint	Maximum apparent power. Minimum: 0.	SPOW
TAPSET	SetPoint	Tap position set point.	ND

BB and BBDEF should be negative. In contrast, those for the line should be positive.

5. Electric external (EXT)

A directed connection to a single electric node, which allows the extraction and injection of power at that node. An electric external is used to model demands, generators, and storage facilities in an electric network. An arbitrary number of electric externals can be assigned to an electric node.

5.1. Electric demand (EDEM)

An object for representing electricity demand at a particular node. It can be controlled by defining a power set-point.

Summaries for the properties and events of EDEM.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of EDEM.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

Summary for the base-result properties of EDEM, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW

Summary for the base-result properties of EDEM, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW

Summary for the base-result properties of EDEM, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC

Summary for the base-result properties of EDEM, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of EDEM.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of EDEM, which are applicable in ACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of EDEM, which are applicable in UACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of EDEM, which are applicable in DCUCOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of EDEM, which are applicable in ACOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of EDEM.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW

Summary for the event-default properties of EDEM, which are applicable in ACPF.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW

Summary for the event-default properties of EDEM, which are applicable in UACPF.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW

Summary for the event-default properties of EDEM, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC

Summary for the event-default properties of EDEM, which are applicable in ACOPF.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of EDEM.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PAVG	Average active power demand over the optimization time horizon in a DCUCOPF scenario. PAVG event can be overruled by a PSET event. If the PAVG event is not overruled by a PSET event, the event value will be maintained for the rest of the simulation time window	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW

Summary for the event-value properties of EDEM, which are applicable in ACPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW

Summary for the event-value properties of EDEM, which are applicable in UACPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW

Summary for the event-value properties of EDEM, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PAVG	Average active power demand over the optimization time horizon in a DCUCOPF scenario. PAVG event can be overruled by a PSET event. If the PAVG event is not overruled by a PSET event, the event value will be maintained for the rest of the simulation time window	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC

Summary for the event-value properties of EDEM, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of EDEM.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
LOADTYPE	How the load is connected between phases and (or) neutral, valid values are Wye (balanced), Delta (balanced), A, B, C, AB, BC, or CA	NO
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
PWF	Power factor (apparent power magnitude divided by active power). Must be greater than 0 and no more than 1. If the reactive power is not set, will calculate a reactive power set-point based on this value, the power factor type and the active power set-point	ND
PWFType	Power factor type. "ind" means lagging (inductive), while "cap" means leading (capacitive). The value does not matter for a unity (resistive) power factor. If the reactive power is not set, will calculate a reactive power set-point based on this value, the power factor and the active power set-point	NO
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of EDEM, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
PWF	Power factor (apparent power magnitude divided by active power). Must be greater than 0 and no more than 1. If the reactive power is not set, will calculate a reactive power set-point based on this value, the power factor type and the active power set-point	ND
PWFType	Power factor type. "ind" means lagging (inductive), while "cap" means leading (capacitive). The value does not matter for a unity (resistive) power factor. If the reactive power is not set, will calculate a reactive power set-point based on this value, the power factor and the active power set-point	NO
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of EDEM, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
LOADTYPE	How the load is connected between phases and (or) neutral, valid values are Wye (balanced), Delta (balanced), A, B, C, AB, BC, or CA	NO
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
PWF	Power factor (apparent power magnitude divided by active power). Must be greater than 0 and no more than 1. If the reactive power is not set, will calculate a reactive power set-point based on this value, the power factor type and the active power set-point	ND
PWFType	Power factor type. "ind" means lagging (inductive), while "cap" means leading (capacitive). The value does not matter for a unity (resistive) power factor. If the reactive power is not set, will calculate a reactive power set-point based on this value, the power factor and the active power set-point	NO
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of EDEM, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of EDEM, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
PWF	Power factor (apparent power magnitude divided by active power). Must be greater than 0 and no more than 1. If the reactive power is not set, will calculate a reactive power set-point based on this value, the power factor type and the active power set-point	ND
PWFType	Power factor type. "ind" means lagging (inductive), while "cap" means leading (capacitive). The value does not matter for a unity (resistive) power factor. If the reactive power is not set, will calculate a reactive power set-point based on this value, the power factor and the active power set-point	NO
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of EDEM.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EDEM, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EDEM, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EDEM, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EDEM, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of EDEM.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PAVG	SetPoint	Average active power demand. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW

Summary for the events of EDEM, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW

Summary for the events of EDEM, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW

Summary for the events of EDEM, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PAVG	SetPoint	Average active power demand. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC

Summary for the events of EDEM, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW

5.2. Electric storage (ESTR)

An object for representing electricity storage at a particular node. An electric storage can supply or absorb power from the network depending on its control mode and the network conditions. Typically, the rate at which power can be injected into or withdrawn from the electric storage depends on its properties (ramp rates, maximum discharge power, etc.). It can also contribute to an ancillary service (up and down reserves) depending on its state of charge.

Summaries for the properties and events of ESTR.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of ESTR.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC
SOC	State of charge for the in service storage(s). When referred to the node is calculated as the weighted energy average stored (in %)	PC

Summary for the base-result properties of ESTR, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
SOC	State of charge for the in service storage(s). When referred to the node is calculated as the weighted energy average stored (in %)	PC

Summary for the base-result properties of ESTR, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
SOC	State of charge for the in service storage(s). When referred to the node is calculated as the weighted energy average stored (in %)	PC

Summary for the base-result properties of ESTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
SOC	State of charge for the in service storage(s). When referred to the node is calculated as the weighted energy average stored (in %)	PC

Summary for the base-result properties of ESTR, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC
SOC	State of charge for the in service storage(s). When referred to the node is calculated as the weighted energy average stored (in %)	PC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of ESTR.
Extension	Description	UnitType
PL	Active power loss storage	PPOW
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
TOTCOSTRATE	Total variable operational and maintenance cost rate	PRCDOT
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of ESTR, which are applicable in ACPF.
Extension	Description	UnitType
PL	Active power loss storage	PPOW
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of ESTR, which are applicable in UACPF.
Extension	Description	UnitType
PL	Active power loss storage	PPOW
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of ESTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
PL	Active power loss storage	PPOW
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
TOTCOSTRATE	Total variable operational and maintenance cost rate	PRCDOT
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of ESTR, which are applicable in ACOPF.
Extension	Description	UnitType
PL	Active power loss storage	PPOW
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of ESTR.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAXDEF	Default maximum charge rate for storage	PPOW
PDMAXPRCDEF	Default penalty price for maximum charge rate for storage	NRGPRC
PGMAXDEF	Default maximum discharge rate	PPOW
PGMAXPRCDEF	Default penalty price for maximum discharge rate	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAXDEF	Default maximum reactive power	QPOW
MaxCapDef	Default Maximum storage capacity	NRG
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PDMINDEF	Default minimum charge rate for storage	PPOW
PDMINPRCDEF	Default penalty price for min charge rate for storage	NRGPRC
PGMINDEF	Default minimum discharge rate	PPOW
PGMINPRCDEF	Default penalty price for minimum discharge rate	NRGPRC
MinDownTimeDDDef	Default minimum down time between consecutive charging operations	TIME
MinDownTimeDGDef	Default minimum down time between consecutive charging-discharging operations	TIME
MinDownTimeGDDef	Default minimum down time between consecutive discharging-charging operations	TIME
MinDownTimeGGDef	Default minimum down time between consecutive discharging operations	TIME
QMINDEF	Default minimum reactive power	QPOW
MinUpTimeDDef	Default minimum up time for charging operation	TIME
MinUpTimeGDef	Default minimum up time for discharging operation	TIME
QSETDEF	Default total reactive power set point	QPOW
SOCMAXPRCDEF	Default penalty price for violating state of charge maximum constraint	NRGPRC
SOCMINPRCDEF	Default penalty price for violating state of charge minimum constraint	NRGPRC
SOCSETPRCDEF	Default penalty price for violating state of charge set point	NRGPRC
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the event-default properties of ESTR, which are applicable in ACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAXDEF	Default maximum charge rate for storage	PPOW
PGMAXDEF	Default maximum discharge rate	PPOW
QMAXDEF	Default maximum reactive power	QPOW
MaxCapDef	Default Maximum storage capacity	NRG
PDMINDEF	Default minimum charge rate for storage	PPOW
PGMINDEF	Default minimum discharge rate	PPOW
QMINDEF	Default minimum reactive power	QPOW
QSETDEF	Default total reactive power set point	QPOW

Summary for the event-default properties of ESTR, which are applicable in UACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAXDEF	Default maximum charge rate for storage	PPOW
PGMAXDEF	Default maximum discharge rate	PPOW
QMAXDEF	Default maximum reactive power	QPOW
MaxCapDef	Default Maximum storage capacity	NRG
PDMINDEF	Default minimum charge rate for storage	PPOW
PGMINDEF	Default minimum discharge rate	PPOW
QMINDEF	Default minimum reactive power	QPOW
QSETDEF	Default total reactive power set point	QPOW

Summary for the event-default properties of ESTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAXDEF	Default maximum charge rate for storage	PPOW
PGMAXDEF	Default maximum discharge rate	PPOW
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxCapDef	Default Maximum storage capacity	NRG
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PDMINDEF	Default minimum charge rate for storage	PPOW
PGMINDEF	Default minimum discharge rate	PPOW
MinDownTimeDDDef	Default minimum down time between consecutive charging operations	TIME
MinDownTimeDGDef	Default minimum down time between consecutive charging-discharging operations	TIME
MinDownTimeGDDef	Default minimum down time between consecutive discharging-charging operations	TIME
MinDownTimeGGDef	Default minimum down time between consecutive discharging operations	TIME
MinUpTimeDDef	Default minimum up time for charging operation	TIME
MinUpTimeGDef	Default minimum up time for discharging operation	TIME
SOCMAXPRCDEF	Default penalty price for violating state of charge maximum constraint	NRGPRC
SOCMINPRCDEF	Default penalty price for violating state of charge minimum constraint	NRGPRC
SOCSETPRCDEF	Default penalty price for violating state of charge set point	NRGPRC
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the event-default properties of ESTR, which are applicable in ACOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAXDEF	Default maximum charge rate for storage	PPOW
PDMAXPRCDEF	Default penalty price for maximum charge rate for storage	NRGPRC
PGMAXDEF	Default maximum discharge rate	PPOW
PGMAXPRCDEF	Default penalty price for maximum discharge rate	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
MaxCapDef	Default Maximum storage capacity	NRG
PDMINDEF	Default minimum charge rate for storage	PPOW
PDMINPRCDEF	Default penalty price for min charge rate for storage	NRGPRC
PGMINDEF	Default minimum discharge rate	PPOW
PGMINPRCDEF	Default penalty price for minimum discharge rate	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
QSETDEF	Default total reactive power set point	QPOW
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of ESTR.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAX	Maximum charge rate for storage	PPOW
PDMAXPRC	Penalty price for maximum charge rate for storage	NRGPRC
PGMAX	Maximum discharge rate	PPOW
PGMAXPRC	Penalty price for maximum discharge rate	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAX	Maximum reactive power	QPOW
SOCMAX	Maximum state of charge	PC
MaxCap	Maximum storage capacity	NRG
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PDMIN	Minimum charge rate for storage	PPOW
PDMINPRC	Penalty price for minimum charge rate for storage	NRGPRC
PGMIN	Minimum discharge rate	PPOW
PGMINPRC	Penalty price for minimum discharge rate	NRGPRC
MinDownTimeDD	Minimum down time between consecutive charging operations	TIME
MinDownTimeDG	Minimum down time between consecutive charging-discharging operations	TIME
MinDownTimeGD	Minimum down time between consecutive discharging-charging operations	TIME
MinDownTimeGG	Minimum down time between consecutive discharging operations	TIME
QMIN	Minimum reactive power	QPOW
SOCMIN	Minimum state of charge	PC
MinUpTimeD	Minimum up time for charging operation	TIME
MinUpTimeG	Minimum up time for discharging operation	TIME
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
SOCMINPRC	Penalty price for violating state of charge minimum constraint	NRGPRC
SOCMAXPRC	Penalty price for violating state of charge maximum constraint	NRGPRC
SOCSET	State of charge set point	PC
SOCSETPRC	Penalty price for violating state of charge set point	NRGPRC
VMSET	Voltage magnitude set point	PU
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the event-value properties of ESTR, which are applicable in ACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAX	Maximum charge rate for storage	PPOW
PGMAX	Maximum discharge rate	PPOW
QMAX	Maximum reactive power	QPOW
MaxCap	Maximum storage capacity	NRG
PDMIN	Minimum charge rate for storage	PPOW
PGMIN	Minimum discharge rate	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of ESTR, which are applicable in UACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAX	Maximum charge rate for storage	PPOW
PGMAX	Maximum discharge rate	PPOW
QMAX	Maximum reactive power	QPOW
MaxCap	Maximum storage capacity	NRG
PDMIN	Minimum charge rate for storage	PPOW
PGMIN	Minimum discharge rate	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of ESTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAX	Maximum charge rate for storage	PPOW
PGMAX	Maximum discharge rate	PPOW
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
SOCMAX	Maximum state of charge	PC
MaxCap	Maximum storage capacity	NRG
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PDMIN	Minimum charge rate for storage	PPOW
PGMIN	Minimum discharge rate	PPOW
MinDownTimeDD	Minimum down time between consecutive charging operations	TIME
MinDownTimeDG	Minimum down time between consecutive charging-discharging operations	TIME
MinDownTimeGD	Minimum down time between consecutive discharging-charging operations	TIME
MinDownTimeGG	Minimum down time between consecutive discharging operations	TIME
SOCMIN	Minimum state of charge	PC
MinUpTimeD	Minimum up time for charging operation	TIME
MinUpTimeG	Minimum up time for discharging operation	TIME
SOCMINPRC	Penalty price for violating state of charge minimum constraint	NRGPRC
SOCMAXPRC	Penalty price for violating state of charge maximum constraint	NRGPRC
SOCSET	State of charge set point	PC
SOCSETPRC	Penalty price for violating state of charge set point	NRGPRC
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the event-value properties of ESTR, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAX	Maximum charge rate for storage	PPOW
PDMAXPRC	Penalty price for maximum charge rate for storage	NRGPRC
PGMAX	Maximum discharge rate	PPOW
PGMAXPRC	Penalty price for maximum discharge rate	NRGPRC
QMAX	Maximum reactive power	QPOW
MaxCap	Maximum storage capacity	NRG
PDMIN	Minimum charge rate for storage	PPOW
PDMINPRC	Penalty price for minimum charge rate for storage	NRGPRC
PGMIN	Minimum discharge rate	PPOW
PGMINPRC	Penalty price for minimum discharge rate	NRGPRC
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
VMSET	Voltage magnitude set point	PU
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of ESTR.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PDeff	Efficiency of charging process	ND
PGeff	Efficiency of discharging process	ND
GENPHASES	Identifies if the generator is three-phase or single-phase, if it is a single-phase, then to which phase it is connected, valid values are A, B, C, or ABC	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of ESTR, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PDeff	Efficiency of charging process	ND
PGeff	Efficiency of discharging process	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of ESTR, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PDeff	Efficiency of charging process	ND
PGeff	Efficiency of discharging process	ND
GENPHASES	Identifies if the generator is three-phase or single-phase, if it is a single-phase, then to which phase it is connected, valid values are A, B, C, or ABC	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of ESTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PDeff	Efficiency of charging process	ND
PGeff	Efficiency of discharging process	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of ESTR, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PDeff	Efficiency of charging process	ND
PGeff	Efficiency of discharging process	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of ESTR.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ESTR, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ESTR, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ESTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ESTR, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of ESTR.
Parameter	Type	Description	UnitType
MAXCAP	Constraint	Maximum storage capacity. Minimum: 0.	NRG
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
MinDownTimeDD	Constraint	Minimum downtime between consecutive charging operations. Minimum: 0.	TIME
MinDownTimeDG	Constraint	Minimum downtime between consecutive charging and discharging operations. Minimum: 0.	TIME
MinDownTimeGD	Constraint	Minimum downtime between consecutive discharging and charging operations. Minimum: 0.	TIME
MinDownTimeGG	Constraint	Minimum downtime between consecutive discharging operations. Minimum: 0.	TIME
MinUpTimeD	Constraint	Minimum up time for charging operation. Minimum: 0.	TIME
MinUpTimeG	Constraint	Minimum up time for discharging operation. Minimum: 0.	TIME
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
ONOFF	State	Enforce unit commitment decision by MIP-Solver.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMAXPRC	PenaltyPrice	Maximum active power charge penalty price. Minimum: 0.	NRGPRC
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PDMINPRC	PenaltyPrice	Minimum active power charge penalty price. Minimum: 0.	NRGPRC
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMAXPRC	PenaltyPrice	Maximum active power discharge penalty price. Minimum: 0.	NRGPRC
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PGMINPRC	PenaltyPrice	Minimum active power discharge penalty price. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	Constraint	Total reactive power set point.	QPOW
SOCMAX	Constraint	Maximum state of charge. Minimum: 0. Maximum: 100.	PC
SOCMAXPRC	PenaltyPrice	Penalty price for state of charge maximum constraint violation. Minimum: 0.	NRGPRC
SOCMIN	Constraint	Minimum state of charge. Minimum: 0. Maximum: 100.	PC
SOCMINPRC	PenaltyPrice	Penalty price for state of charge minimum constraint violation. Minimum: 0.	NRGPRC
SOCSET	StorageSetPoint	State of charge set point. Minimum: 0. Maximum: 100.	PC
SOCSETPRC	PenaltyPrice	Penalty price for state of charge set point violation. Minimum: 0.	NRGPRC
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU
VOMDPrice	Price	Variable operational and maintenance price per charged energy.	NRGPRC
VOMGPrice	Price	Variable operational and maintenance price per discharged energy.	NRGPRC

Summary for the events of ESTR, which are applicable in ACPF.
Parameter	Type	Description	UnitType
MAXCAP	Constraint	Maximum storage capacity. Minimum: 0.	NRG
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	Constraint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of ESTR, which are applicable in UACPF.
Parameter	Type	Description	UnitType
MAXCAP	Constraint	Maximum storage capacity. Minimum: 0.	NRG
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	Constraint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of ESTR, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
MAXCAP	Constraint	Maximum storage capacity. Minimum: 0.	NRG
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
MinDownTimeDD	Constraint	Minimum downtime between consecutive charging operations. Minimum: 0.	TIME
MinDownTimeDG	Constraint	Minimum downtime between consecutive charging and discharging operations. Minimum: 0.	TIME
MinDownTimeGD	Constraint	Minimum downtime between consecutive discharging and charging operations. Minimum: 0.	TIME
MinDownTimeGG	Constraint	Minimum downtime between consecutive discharging operations. Minimum: 0.	TIME
MinUpTimeD	Constraint	Minimum up time for charging operation. Minimum: 0.	TIME
MinUpTimeG	Constraint	Minimum up time for discharging operation. Minimum: 0.	TIME
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
ONOFF	State	Enforce unit commitment decision by MIP-Solver.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
SOCMAX	Constraint	Maximum state of charge. Minimum: 0. Maximum: 100.	PC
SOCMAXPRC	PenaltyPrice	Penalty price for state of charge maximum constraint violation. Minimum: 0.	NRGPRC
SOCMIN	Constraint	Minimum state of charge. Minimum: 0. Maximum: 100.	PC
SOCMINPRC	PenaltyPrice	Penalty price for state of charge minimum constraint violation. Minimum: 0.	NRGPRC
SOCSET	StorageSetPoint	State of charge set point. Minimum: 0. Maximum: 100.	PC
SOCSETPRC	PenaltyPrice	Penalty price for state of charge set point violation. Minimum: 0.	NRGPRC
VOMDPrice	Price	Variable operational and maintenance price per charged energy.	NRGPRC
VOMGPrice	Price	Variable operational and maintenance price per discharged energy.	NRGPRC

Summary for the events of ESTR, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
MAXCAP	Constraint	Maximum storage capacity. Minimum: 0.	NRG
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMAXPRC	PenaltyPrice	Maximum active power charge penalty price. Minimum: 0.	NRGPRC
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PDMINPRC	PenaltyPrice	Minimum active power charge penalty price. Minimum: 0.	NRGPRC
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMAXPRC	PenaltyPrice	Maximum active power discharge penalty price. Minimum: 0.	NRGPRC
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PGMINPRC	PenaltyPrice	Minimum active power discharge penalty price. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW

The initial state of charge (SOC) of an ESTR is 0 % in all scenarios, unless differently defined by the user. This statement is not true for a CEM scenario. The initial SOC in CEM is flexible, but there is a constraint that forces the initial and final step to have the same SOC level.

With the release 3.6 of SAInt, the property VMSETDEF has been removed for ESTR objects. Instead, the property QSETDEF has been added, making electric storages treated in a similar way to WIND and PV objects with a default QSET. The default value of QSETDEF is 0 MVAr.

When opening a model created with a version of SAInt prior to 3.6, users should create a VSET event for instances of the ESTR object in their model. Note that single phase ESTR objects are restricted from the VSET property, and only QSET events can be used.

5.3. Electric shunt (SHT)

An electric shunt models a shunt reactor or capacitor. Shunt reactors are placed locally to control the over-voltages at electric nodes under light load conditions (consume reactive power to reduce the nodal voltage), while shunt capacitors are used to boost the voltage in a stressed system (supply reactive power to increase the nodal voltage).

A positive BSET means the shunt is capacitive, otherwise it is inductive.

Summaries for the properties and events of SHT.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of SHT.
Extension	Description	UnitType
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU

Summary for the base-result properties of SHT, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of SHT, which are applicable in UACPF.
Extension	Description	UnitType
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU

Summary for the base-result properties of SHT, which are applicable in DCUCOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of SHT, which are applicable in ACOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of SHT.
Extension	Description	UnitType
P	Total active power (-) absorbed / (+) injected	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
Q	Total reactive power (-) absorbed / (+) injected	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of SHT, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power (-) absorbed / (+) injected	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
Q	Total reactive power (-) absorbed / (+) injected	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of SHT, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power (-) absorbed / (+) injected	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
Q	Total reactive power (-) absorbed / (+) injected	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of SHT, which are applicable in DCUCOPF.
Extension	Description	UnitType
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of SHT, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power (-) absorbed / (+) injected	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
Q	Total reactive power (-) absorbed / (+) injected	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
ACOPF

Summary for the event-default properties of SHT.
Extension	Description	UnitType
GSETDEF	Dissipated active power at the rated voltage. Used to calculate the shunt conductance	PPOW
BSETDEF	Injected reactive power at the rated voltage. Used to calculate the shunt susceptance. A positive value means the shunt is capacitive, otherwise it is inductive	QPOW

Summary for the event-default properties of SHT, which are applicable in ACPF.
Extension	Description	UnitType
GSETDEF	Dissipated active power at the rated voltage. Used to calculate the shunt conductance	PPOW
BSETDEF	Injected reactive power at the rated voltage. Used to calculate the shunt susceptance. A positive value means the shunt is capacitive, otherwise it is inductive	QPOW

Summary for the event-default properties of SHT, which are applicable in UACPF.
Extension	Description	UnitType
GSETDEF	Dissipated active power at the rated voltage. Used to calculate the shunt conductance	PPOW
BSETDEF	Injected reactive power at the rated voltage. Used to calculate the shunt susceptance. A positive value means the shunt is capacitive, otherwise it is inductive	QPOW

Summary for the event-default properties of SHT, which are applicable in ACOPF.
Extension	Description	UnitType
GSETDEF	Dissipated active power at the rated voltage. Used to calculate the shunt conductance	PPOW
BSETDEF	Injected reactive power at the rated voltage. Used to calculate the shunt susceptance. A positive value means the shunt is capacitive, otherwise it is inductive	QPOW

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of SHT.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
QREF	Reactive power reference	QPOW
GSET	Dissipated active power at the rated voltage. Used to calculate the shunt conductance	PPOW
BSET	Injected reactive power at the rated voltage. Used to calculate the shunt susceptance. A positive value means the shunt is capacitive, otherwise it is inductive	QPOW

Summary for the event-value properties of SHT, which are applicable in ACPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
QREF	Reactive power reference	QPOW
GSET	Dissipated active power at the rated voltage. Used to calculate the shunt conductance	PPOW
BSET	Injected reactive power at the rated voltage. Used to calculate the shunt susceptance. A positive value means the shunt is capacitive, otherwise it is inductive	QPOW

Summary for the event-value properties of SHT, which are applicable in UACPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
QREF	Reactive power reference	QPOW
GSET	Dissipated active power at the rated voltage. Used to calculate the shunt conductance	PPOW
BSET	Injected reactive power at the rated voltage. Used to calculate the shunt susceptance. A positive value means the shunt is capacitive, otherwise it is inductive	QPOW

Summary for the event-value properties of SHT, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW

Summary for the event-value properties of SHT, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
QREF	Reactive power reference	QPOW
GSET	Dissipated active power at the rated voltage. Used to calculate the shunt conductance	PPOW
BSET	Injected reactive power at the rated voltage. Used to calculate the shunt susceptance. A positive value means the shunt is capacitive, otherwise it is inductive	QPOW

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of SHT.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
SHTTYPE	How the shunt is connected between phases and (or) neutral, valid values are Wye (balanced), Delta (balanced), A, B, C, AB, BC, or CA	NO
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of SHT, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of SHT, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
SHTTYPE	How the shunt is connected between phases and (or) neutral, valid values are Wye (balanced), Delta (balanced), A, B, C, AB, BC, or CA	NO
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of SHT, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of SHT, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of SHT.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of SHT, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of SHT, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of SHT, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of SHT, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of SHT.
Parameter	Type	Description	UnitType
BSET	SetPoint	Injected reactive power at rated voltage.	QPOW
GSET	SetPoint	Dissipated active power at rated voltage. Minimum: 0.	PPOW
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW
QREF	Reference	Reactive power reference.	QPOW

Summary for the events of SHT, which are applicable in ACPF.
Parameter	Type	Description	UnitType
BSET	SetPoint	Injected reactive power at rated voltage.	QPOW
GSET	SetPoint	Dissipated active power at rated voltage. Minimum: 0.	PPOW
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW
QREF	Reference	Reactive power reference.	QPOW

Summary for the events of SHT, which are applicable in UACPF.
Parameter	Type	Description	UnitType
BSET	SetPoint	Injected reactive power at rated voltage.	QPOW
GSET	SetPoint	Dissipated active power at rated voltage. Minimum: 0.	PPOW
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW
QREF	Reference	Reactive power reference.	QPOW

Summary for the events of SHT, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
PREF	Reference	Active power reference. Minimum: 0.	PPOW

Summary for the events of SHT, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
BSET	SetPoint	Injected reactive power at rated voltage.	QPOW
GSET	SetPoint	Dissipated active power at rated voltage. Minimum: 0.	PPOW
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PREF	Reference	Active power reference. Minimum: 0.	PPOW
QREF	Reference	Reactive power reference.	QPOW

5.4. Electric prosumer (EPS)

The object models the injection and extraction of electricity from an external network or a device or facility that can generate and consume electricity without storage. For example an electric prosumer object can describe a pumped hydro storage, an external grid, or a generic storage in the electric network. It allows to set an active power discharge (negative P) or charge (positive P).

Summaries for the properties and events of EPS.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of EPS.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

Summary for the base-result properties of EPS, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW

Summary for the base-result properties of EPS, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW

Summary for the base-result properties of EPS, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC

Summary for the base-result properties of EPS, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of EPS.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QREF	Reactive power reference	QPOW
TOTCOSTRATE	Total variable operational and maintenance cost rate	PRCDOT
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the derived-result properties of EPS, which are applicable in ACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QREF	Reactive power reference	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of EPS, which are applicable in UACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QREF	Reactive power reference	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of EPS, which are applicable in DCUCOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
TOTCOSTRATE	Total variable operational and maintenance cost rate	PRCDOT
VA	Voltage Angle	ANGLE
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the derived-result properties of EPS, which are applicable in ACOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QREF	Reactive power reference	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of EPS.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAXDEF	Default maximum active power demand	PPOW
PDMAXPRCDEF	DefMaxActivePowerDemandPenPrice	NRGPRC
PGMAXDEF	DefMaxActivePowerGeneration	PPOW
PGMAXPRCDEF	DefMaxActivePowerGenerationPenPrice	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PDMINDEF	DefMinActivePowerDemand	PPOW
PDMINPRCDEF	DefMinActivePowerDemandPenPrice	NRGPRC
PGMINDEF	DefMinActivePowerGeneration	PPOW
PGMINPRCDEF	DefMinActivePowerGenerationPenPrice	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of EPS, which are applicable in ACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAXDEF	Default maximum active power demand	PPOW
PGMAXDEF	DefMaxActivePowerGeneration	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PDMINDEF	DefMinActivePowerDemand	PPOW
PGMINDEF	DefMinActivePowerGeneration	PPOW
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of EPS, which are applicable in UACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAXDEF	Default maximum active power demand	PPOW
PGMAXDEF	DefMaxActivePowerGeneration	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PDMINDEF	DefMinActivePowerDemand	PPOW
PGMINDEF	DefMinActivePowerGeneration	PPOW
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of EPS, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAXDEF	Default maximum active power demand	PPOW
PGMAXDEF	DefMaxActivePowerGeneration	PPOW
PDMINDEF	DefMinActivePowerDemand	PPOW
PGMINDEF	DefMinActivePowerGeneration	PPOW

Summary for the event-default properties of EPS, which are applicable in ACOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAXDEF	Default maximum active power demand	PPOW
PDMAXPRCDEF	DefMaxActivePowerDemandPenPrice	NRGPRC
PGMAXDEF	DefMaxActivePowerGeneration	PPOW
PGMAXPRCDEF	DefMaxActivePowerGenerationPenPrice	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PDMINDEF	DefMinActivePowerDemand	PPOW
PDMINPRCDEF	DefMinActivePowerDemandPenPrice	NRGPRC
PGMINDEF	DefMinActivePowerGeneration	PPOW
PGMINPRCDEF	DefMinActivePowerGenerationPenPrice	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of EPS.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAX	Maximum active power demand	PPOW
PDMAXPRC	MaxActivePowerDemandPenPrice	NRGPRC
PGMAX	MaxActivePowerGeneration	PPOW
PGMAXPRC	MaxActivePowerGenerationPenPrice	NRGPRC
QMAX	Maximum reactive power	QPOW
PDMIN	MinActivePowerDemand	PPOW
PDMINPRC	MinActivePowerDemandPenPrice	NRGPRC
PGMIN	MinActivePowerGeneration	PPOW
PGMINPRC	MinActivePowerGenerationPenPrice	NRGPRC
QMIN	Minimum reactive power	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of EPS, which are applicable in ACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAX	Maximum active power demand	PPOW
PGMAX	MaxActivePowerGeneration	PPOW
QMAX	Maximum reactive power	QPOW
PDMIN	MinActivePowerDemand	PPOW
PGMIN	MinActivePowerGeneration	PPOW
QMIN	Minimum reactive power	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of EPS, which are applicable in UACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAX	Maximum active power demand	PPOW
PGMAX	MaxActivePowerGeneration	PPOW
QMAX	Maximum reactive power	QPOW
PDMIN	MinActivePowerDemand	PPOW
PGMIN	MinActivePowerGeneration	PPOW
QMIN	Minimum reactive power	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of EPS, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAX	Maximum active power demand	PPOW
PGMAX	MaxActivePowerGeneration	PPOW
PDMIN	MinActivePowerDemand	PPOW
PGMIN	MinActivePowerGeneration	PPOW

Summary for the event-value properties of EPS, which are applicable in ACOPF.
Extension	Description	UnitType
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PDMAX	Maximum active power demand	PPOW
PDMAXPRC	MaxActivePowerDemandPenPrice	NRGPRC
PGMAX	MaxActivePowerGeneration	PPOW
PGMAXPRC	MaxActivePowerGenerationPenPrice	NRGPRC
QMAX	Maximum reactive power	QPOW
PDMIN	MinActivePowerDemand	PPOW
PDMINPRC	MinActivePowerDemandPenPrice	NRGPRC
PGMIN	MinActivePowerGeneration	PPOW
PGMINPRC	MinActivePowerGenerationPenPrice	NRGPRC
QMIN	Minimum reactive power	QPOW
VMSET	Voltage magnitude set point	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of EPS.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of EPS, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of EPS, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of EPS, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of EPS, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of EPS.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EPS, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EPS, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EPS, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EPS, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of EPS.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMAXPRC	PenaltyPrice	Maximum active power charge penalty price. Minimum: 0.	NRGPRC
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PDMINPRC	PenaltyPrice	Minimum active power charge penalty price. Minimum: 0.	NRGPRC
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMAXPRC	PenaltyPrice	Maximum active power discharge penalty price. Minimum: 0.	NRGPRC
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PGMINPRC	PenaltyPrice	Minimum active power discharge penalty price. Minimum: 0.	NRGPRC
PSET	SetPoint	Total active power set point.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QSET	Constraint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 1.5.	PU

Summary for the events of EPS, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW

Summary for the events of EPS, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QSET	Constraint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 1.5.	PU

Summary for the events of EPS, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMAXPRC	PenaltyPrice	Maximum active power charge penalty price. Minimum: 0.	NRGPRC
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PDMINPRC	PenaltyPrice	Minimum active power charge penalty price. Minimum: 0.	NRGPRC
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMAXPRC	PenaltyPrice	Maximum active power discharge penalty price. Minimum: 0.	NRGPRC
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PGMINPRC	PenaltyPrice	Minimum active power discharge penalty price. Minimum: 0.	NRGPRC
PSET	SetPoint	Total active power set point.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC

Summary for the events of EPS, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMAXPRC	PenaltyPrice	Maximum active power charge penalty price. Minimum: 0.	NRGPRC
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PDMINPRC	PenaltyPrice	Minimum active power charge penalty price. Minimum: 0.	NRGPRC
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMAXPRC	PenaltyPrice	Maximum active power discharge penalty price. Minimum: 0.	NRGPRC
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PGMINPRC	PenaltyPrice	Minimum active power discharge penalty price. Minimum: 0.	NRGPRC
PSET	SetPoint	Total active power set point.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC

5.5. Pumped hydro storage (PHSTR)

The object models a storage facility that extracts electricity from a network for pumping water into a reservoir using an electric pump and injects electricity into a network by converting the potential energy stored in the reservoir to electric energy using a hydro generator. A pumped hydro storage is always connected to a hydro power plant.

Summaries for the properties and events of PHSTR.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of PHSTR.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
StateTime	Time duration of the current state of the facility	TIME
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

Summary for the base-result properties of PHSTR, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW

Summary for the base-result properties of PHSTR, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
StateTime	Time duration of the current state of the facility	TIME
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW

Summary for the base-result properties of PHSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC

Summary for the base-result properties of PHSTR, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of PHSTR.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
COST	Operational cost as a function of active power generation	C
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
TOTCOSTRATE	Total variable operational and maintenance cost rate	PRCDOT
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of PHSTR, which are applicable in ACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of PHSTR, which are applicable in UACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of PHSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
TOTCOSTRATE	Total variable operational and maintenance cost rate	PRCDOT
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of PHSTR, which are applicable in ACOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
COST	Operational cost as a function of active power generation	C
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of PHSTR.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
PDMAXDEF	Default max demand rate for pumping	PPOW
PDMAXPRCDEF	Default penalty price for max demand rate for pumping	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PGMAXDEF	Default max generation rate by turbination	PPOW
PGMAXPRCDEF	Default penalty price for max generation rate by turbination	NRGPRC
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
MinDownTimeDDDef	Default minimum down time between consecutive pumping operations	TIME
MinDownTimeDGDef	Default minimum down time between consecutive pumping-generating operations	TIME
MinDownTimeGDDef	Default minimum down time between consecutive generating-pumping operations	TIME
MinDownTimeGGDef	Default minimum down time between consecutive generating operations	TIME
PDMINDEF	Default min demand rate for pumping	PPOW
PDMINPRCDEF	Default penalty price for min demand rate for pumping	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
PGMINDEF	Default min generation rate by turbination	PPOW
PGMINPRCDEF	Default penalty price for min generation rate by turbination	NRGPRC
MinUpTimeDDef	Default minimum up time for pumping operation	TIME
MinUpTimeGDef	Default minimum up time for generating operation	TIME
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
VMSETDEF	Default voltage magnitude set point	PU
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the event-default properties of PHSTR, which are applicable in ACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAXDEF	Default max demand rate for pumping	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PGMAXDEF	Default max generation rate by turbination	PPOW
PDMINDEF	Default min demand rate for pumping	PPOW
QMINDEF	Default minimum reactive power	QPOW
PGMINDEF	Default min generation rate by turbination	PPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of PHSTR, which are applicable in UACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAXDEF	Default max demand rate for pumping	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PGMAXDEF	Default max generation rate by turbination	PPOW
PDMINDEF	Default min demand rate for pumping	PPOW
QMINDEF	Default minimum reactive power	QPOW
PGMINDEF	Default min generation rate by turbination	PPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of PHSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
PDMAXDEF	Default max demand rate for pumping	PPOW
PGMAXDEF	Default max generation rate by turbination	PPOW
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
MinDownTimeDDDef	Default minimum down time between consecutive pumping operations	TIME
MinDownTimeDGDef	Default minimum down time between consecutive pumping-generating operations	TIME
MinDownTimeGDDef	Default minimum down time between consecutive generating-pumping operations	TIME
MinDownTimeGGDef	Default minimum down time between consecutive generating operations	TIME
PDMINDEF	Default min demand rate for pumping	PPOW
PGMINDEF	Default min generation rate by turbination	PPOW
MinUpTimeDDef	Default minimum up time for pumping operation	TIME
MinUpTimeGDef	Default minimum up time for generating operation	TIME
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the event-default properties of PHSTR, which are applicable in ACOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PDMAXDEF	Default max demand rate for pumping	PPOW
PDMAXPRCDEF	Default penalty price for max demand rate for pumping	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PGMAXDEF	Default max generation rate by turbination	PPOW
PGMAXPRCDEF	Default penalty price for max generation rate by turbination	NRGPRC
PDMINDEF	Default min demand rate for pumping	PPOW
PDMINPRCDEF	Default penalty price for min demand rate for pumping	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
PGMINDEF	Default min generation rate by turbination	PPOW
PGMINPRCDEF	Default penalty price for min generation rate by turbination	NRGPRC
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
VMSETDEF	Default voltage magnitude set point	PU
VOMDPriceDef	Default variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPriceDef	Default variable operational and maintenance cost per generated/discharged energy	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of PHSTR.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
PDMAX	Max demand rate for pumping	PPOW
PDMAXPRC	Penalty price for max demand rate for pumping	NRGPRC
QMAX	Maximum reactive power	QPOW
PGMAX	Max generation rate by turbination	PPOW
PGMAXPRC	Penalty price for max generation rate by turbination	NRGPRC
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
MinDownTimeDD	Minimum down time between consecutive pumping operations	TIME
MinDownTimeDG	Minimum down time between consecutive pumping-generating operations	TIME
MinDownTimeGD	Minimum down time between consecutive generating-pumping operations	TIME
MinDownTimeGG	Minimum down time between consecutive generating operations	TIME
PDMIN	Min demand rate for pumping	PPOW
PDMINPRC	Penalty price for min demand rate for pumping	NRGPRC
QMIN	Minimum reactive power	QPOW
PGMIN	Min generation rate by turbination	PPOW
PGMINPRC	Penalty price for min generation rate by turbination	NRGPRC
MinUpTimeD	Minimum up time for pumping operation	TIME
MinUpTimeG	Minimum up time for generating operation	TIME
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the event-value properties of PHSTR, which are applicable in ACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAX	Max demand rate for pumping	PPOW
QMAX	Maximum reactive power	QPOW
PGMAX	Max generation rate by turbination	PPOW
PDMIN	Min demand rate for pumping	PPOW
QMIN	Minimum reactive power	QPOW
PGMIN	Min generation rate by turbination	PPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of PHSTR, which are applicable in UACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PDMAX	Max demand rate for pumping	PPOW
QMAX	Maximum reactive power	QPOW
PGMAX	Max generation rate by turbination	PPOW
PDMIN	Min demand rate for pumping	PPOW
QMIN	Minimum reactive power	QPOW
PGMIN	Min generation rate by turbination	PPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of PHSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
PDMAX	Max demand rate for pumping	PPOW
PGMAX	Max generation rate by turbination	PPOW
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
MinDownTimeDD	Minimum down time between consecutive pumping operations	TIME
MinDownTimeDG	Minimum down time between consecutive pumping-generating operations	TIME
MinDownTimeGD	Minimum down time between consecutive generating-pumping operations	TIME
MinDownTimeGG	Minimum down time between consecutive generating operations	TIME
PDMIN	Min demand rate for pumping	PPOW
PGMIN	Min generation rate by turbination	PPOW
MinUpTimeD	Minimum up time for pumping operation	TIME
MinUpTimeG	Minimum up time for generating operation	TIME
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

Summary for the event-value properties of PHSTR, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PDMAX	Max demand rate for pumping	PPOW
PDMAXPRC	Penalty price for max demand rate for pumping	NRGPRC
QMAX	Maximum reactive power	QPOW
PGMAX	Max generation rate by turbination	PPOW
PGMAXPRC	Penalty price for max generation rate by turbination	NRGPRC
PDMIN	Min demand rate for pumping	PPOW
PDMINPRC	Penalty price for min demand rate for pumping	NRGPRC
QMIN	Minimum reactive power	QPOW
PGMIN	Min generation rate by turbination	PPOW
PGMINPRC	Penalty price for min generation rate by turbination	NRGPRC
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
VMSET	Voltage magnitude set point	PU
VOMDPrice	Variable operational and maintenance cost per stored/charged energy	NRGPRC
VOMGPrice	Variable operational and maintenance cost per generated/discharged energy	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of PHSTR.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PDCOEFF	Active power consumption per volumetric flow rate pumped by hydro pump	POWQVOL
PGCOEFF	Active power generation per volumetric flow rate driving hydro turbine	POWQVOL
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXN	Neutral reactance in per unit on the object base	PU
RRN	Neutral resistance in per unit on the object base	PU
NodeName	Name of node the external is connected to
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of PHSTR, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of PHSTR, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXN	Neutral reactance in per unit on the object base	PU
RRN	Neutral resistance in per unit on the object base	PU
NodeName	Name of node the external is connected to
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of PHSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PDCOEFF	Active power consumption per volumetric flow rate pumped by hydro pump	POWQVOL
PGCOEFF	Active power generation per volumetric flow rate driving hydro turbine	POWQVOL
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of PHSTR, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of PHSTR.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of PHSTR, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of PHSTR, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of PHSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of PHSTR, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of PHSTR.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
MinDownTimeDD	Constraint	Minimum downtime between consecutive pumping operations. Minimum: 0.	TIME
MinDownTimeDG	Constraint	Minimum downtime between consecutive pumping and generating operations. Minimum: 0.	TIME
MinDownTimeGD	Constraint	Minimum downtime between consecutive generating and pumping operations. Minimum: 0.	TIME
MinDownTimeGG	Constraint	Minimum downtime between consecutive generating operations. Minimum: 0.	TIME
MinUpTimeD	Constraint	Minimum up time for pumping operation. Minimum: 0.	TIME
MinUpTimeG	Constraint	Minimum up time for generating operation. Minimum: 0.	TIME
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
ONOFF	State	Enforce unit commitment decision by MIP-Solver.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMAXPRC	PenaltyPrice	Penalty price for maximum power demand. Minimum: 0.	NRGPRC
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PDMINPRC	PenaltyPrice	Penalty price for minimum power demand. Minimum: 0.	NRGPRC
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMAXPRC	PenaltyPrice	Penalty price for maximum power generation. Minimum: 0.	NRGPRC
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PGMINPRC	PenaltyPrice	Penalty price for minimum power generation. Minimum: 0.	NRGPRC
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU
VOMDPrice	Price	Variable operational and maintenance price.	NRGPRC
VOMGPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of PHSTR, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of PHSTR, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of PHSTR, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
MinDownTimeDD	Constraint	Minimum downtime between consecutive pumping operations. Minimum: 0.	TIME
MinDownTimeDG	Constraint	Minimum downtime between consecutive pumping and generating operations. Minimum: 0.	TIME
MinDownTimeGD	Constraint	Minimum downtime between consecutive generating and pumping operations. Minimum: 0.	TIME
MinDownTimeGG	Constraint	Minimum downtime between consecutive generating operations. Minimum: 0.	TIME
MinUpTimeD	Constraint	Minimum up time for pumping operation. Minimum: 0.	TIME
MinUpTimeG	Constraint	Minimum up time for generating operation. Minimum: 0.	TIME
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
ONOFF	State	Enforce unit commitment decision by MIP-Solver.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMAXPRC	PenaltyPrice	Penalty price for maximum power demand. Minimum: 0.	NRGPRC
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PDMINPRC	PenaltyPrice	Penalty price for minimum power demand. Minimum: 0.	NRGPRC
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMAXPRC	PenaltyPrice	Penalty price for maximum power generation. Minimum: 0.	NRGPRC
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PGMINPRC	PenaltyPrice	Penalty price for minimum power generation. Minimum: 0.	NRGPRC
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
VOMDPrice	Price	Variable operational and maintenance price.	NRGPRC
VOMGPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of PHSTR, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PDMAX	Constraint	Maximum charge rate. Minimum: 0.	PPOW
PDMAXPRC	PenaltyPrice	Penalty price for maximum power demand. Minimum: 0.	NRGPRC
PDMIN	Constraint	Minimum charge rate. Minimum: 0.	PPOW
PDMINPRC	PenaltyPrice	Penalty price for minimum power demand. Minimum: 0.	NRGPRC
PGMAX	Constraint	Maximum discharge rate. Minimum: 0.	PPOW
PGMAXPRC	PenaltyPrice	Penalty price for maximum power generation. Minimum: 0.	NRGPRC
PGMIN	Constraint	Minimum discharge rate. Minimum: 0.	PPOW
PGMINPRC	PenaltyPrice	Penalty price for minimum power generation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
VOMDPrice	Price	Variable operational and maintenance price.	NRGPRC
VOMGPrice	Price	Variable operational and maintenance price.	NRGPRC

5.6. Generic generator (XGEN)

An object for representing a generic electricity generator. For example, it can represent a solar generator, wind generator, bio fuel generator, etc. It can also contribute to an ancillary service (up and down reserves).

Summaries for the properties and events of XGEN.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of XGEN.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

Summary for the base-result properties of XGEN, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW

Summary for the base-result properties of XGEN, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW

Summary for the base-result properties of XGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC

Summary for the base-result properties of XGEN, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of XGEN.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
COST	Operational cost as a function of active power generation	C
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of XGEN, which are applicable in ACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of XGEN, which are applicable in UACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of XGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of XGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
COST	Operational cost as a function of active power generation	C
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of XGEN.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAXDEF	Default maximum reactive power	QPOW
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
VMSETDEF	Default voltage magnitude set point	PU
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of XGEN, which are applicable in ACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of XGEN, which are applicable in UACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of XGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of XGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
VMSETDEF	Default voltage magnitude set point	PU
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of XGEN.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAX	Maximum reactive power	QPOW
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of XGEN, which are applicable in ACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of XGEN, which are applicable in UACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of XGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of XGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of XGEN.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXN	Neutral reactance in per unit on the object base	PU
RRN	Neutral resistance in per unit on the object base	PU
NodeName	Name of node the external is connected to
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of XGEN, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of XGEN, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXN	Neutral reactance in per unit on the object base	PU
RRN	Neutral resistance in per unit on the object base	PU
NodeName	Name of node the external is connected to
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of XGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of XGEN, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of XGEN.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of XGEN, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of XGEN, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of XGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of XGEN, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of XGEN.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of XGEN, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of XGEN, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of XGEN, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of XGEN, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

5.7. Hydro generator (HGEN)

A hydro generator object requires a connection to a hydro plant object. Electricity generation for hydro generators is determined by the flow of water through a hydro turbine at the hydro plant. It can also contribute to an ancillary service (up and down reserves) depending upon the volume of the hydro plant.

Summaries for the properties and events of HGEN.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of HGEN.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

Summary for the base-result properties of HGEN, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW

Summary for the base-result properties of HGEN, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW

Summary for the base-result properties of HGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC

Summary for the base-result properties of HGEN, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of HGEN.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
COST	Operational cost as a function of active power generation	C
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of HGEN, which are applicable in ACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of HGEN, which are applicable in UACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of HGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of HGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
COST	Operational cost as a function of active power generation	C
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of HGEN.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAXDEF	Default maximum reactive power	QPOW
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
VMSETDEF	Default voltage magnitude set point	PU
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of HGEN, which are applicable in ACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of HGEN, which are applicable in UACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of HGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of HGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
VMSETDEF	Default voltage magnitude set point	PU
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of HGEN.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAX	Maximum reactive power	QPOW
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of HGEN, which are applicable in ACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of HGEN, which are applicable in UACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of HGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of HGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of HGEN.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
PCOEFF	Active power generation per volumetric flow rate driving hydro turbine	POWQVOL
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXN	Neutral reactance in per unit on the object base	PU
RRN	Neutral resistance in per unit on the object base	PU
NodeName	Name of node the external is connected to
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of HGEN, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of HGEN, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXN	Neutral reactance in per unit on the object base	PU
RRN	Neutral resistance in per unit on the object base	PU
NodeName	Name of node the external is connected to
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of HGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
PCOEFF	Active power generation per volumetric flow rate driving hydro turbine	POWQVOL
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of HGEN, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
PlantName	Name of the hydro power plant the generator belongs to	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of HGEN.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of HGEN, which are applicable in ACPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of HGEN, which are applicable in UACPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of HGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of HGEN, which are applicable in ACOPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of HGEN.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of HGEN, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of HGEN, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of HGEN, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of HGEN, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

A model prepared in SAInt version 3.2.X opened in version 3.3 or later, SAInt converts the hydro generator HGEN objects into a pumped hydro storage PHSTR objects. Pumped hydro storage objects are two-sided externals. Therefore, the PMIN property of the HGEN will be converted to PGMIN property and the PMAX will be converted to PGMAX. The value of the VOMPrice will be copied to VOMGPrice and VOMDPrice properties of the PHSTR. Once a scenario is run, the corresponding events, if any, will also be mapped to the PHSTR object automatically.

5.8. Fuel generator (FGEN)

Fuel generators require a connection to a fuel object, and electricity generation from a fuel generator incurs costs and emissions associated with the fuel object. It can also contribute to an ancillary service (up and down reserves).

Summaries for the properties and events of FGEN.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of FGEN.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
StateTime	Time duration of the current state of the facility	TIME
F	Total fuel consumption per time	NO
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

Summary for the base-result properties of FGEN, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW

Summary for the base-result properties of FGEN, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
StateTime	Time duration of the current state of the facility	TIME
EA	Phase A internal voltage angle	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW

Summary for the base-result properties of FGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
F	Total fuel consumption per time	NO
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC

Summary for the base-result properties of FGEN, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
StateTime	Time duration of the current state of the facility	TIME
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of FGEN.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
CO2RATE	Emission rate of carbon dioxide per time	EMDOT
COST	Operational cost as a function of active power generation	C
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
LINFC	Hourly fuel consumption as a function of active power	NO
FuelCostRate	Fuel cost rate per time	PRCDOT
HR	Heat rate as a function of active power generation	HR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
MARGPRCLINFC	Marginal price for linearized quadratic fuel consumption curve	NRGPRC
MARGPRCQUADFC	Marginal price for quadratic fuel consumption curve	NRGPRC
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
NOXRATE	Emission rate of nitrogen oxides per time	EMDOT
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
QUADFC	Hourly fuel consumption as a quadratic function of active power generation	NO
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
ShutDown	Indicates if the generator has shut down between current time step and previous time step	ND
ShutDownCostRate	Shutdown cost between current time step and previous time step	C
SO2RATE	Total emission rate of sulfur dioxide per time. When referred to a node, network, subs, zones, or groups, it is calculated as the sum of the emission rates (SO2RATE) of all fuel generators assigned to the node, network, subs, zones, or groups	EMDOT
StartUp	Indicates if the generator has startup between current time step and previous time step	ND
StartUpCostRate	Shutdown cost between current time step and previous time step	C
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of FGEN, which are applicable in ACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
HR	Heat rate as a function of active power generation	HR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
ShutDown	Indicates if the generator has shut down between current time step and previous time step	ND
StartUp	Indicates if the generator has startup between current time step and previous time step	ND
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of FGEN, which are applicable in UACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
HR	Heat rate as a function of active power generation	HR
EVOLT	Internal phase voltage magnitude	VOLT
EM	Internal voltage magnitude in per unit of the rated voltage	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
ShutDown	Indicates if the generator has shut down between current time step and previous time step	ND
StartUp	Indicates if the generator has startup between current time step and previous time step	ND
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of FGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
CO2RATE	Emission rate of carbon dioxide per time	EMDOT
LINFC	Hourly fuel consumption as a function of active power	NO
FuelCostRate	Fuel cost rate per time	PRCDOT
MARGPRCLINFC	Marginal price for linearized quadratic fuel consumption curve	NRGPRC
MARGPRCQUADFC	Marginal price for quadratic fuel consumption curve	NRGPRC
NOXRATE	Emission rate of nitrogen oxides per time	EMDOT
QUADFC	Hourly fuel consumption as a quadratic function of active power generation	NO
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
ShutDown	Indicates if the generator has shut down between current time step and previous time step	ND
ShutDownCostRate	Shutdown cost between current time step and previous time step	C
SO2RATE	Total emission rate of sulfur dioxide per time. When referred to a node, network, subs, zones, or groups, it is calculated as the sum of the emission rates (SO2RATE) of all fuel generators assigned to the node, network, subs, zones, or groups	EMDOT
StartUp	Indicates if the generator has startup between current time step and previous time step	ND
StartUpCostRate	Shutdown cost between current time step and previous time step	C
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
PRSVDOWN	Total power contribution to downward reserves	PPOW
PRSVUP	Total power contribution to upward reserves	PPOW
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of FGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
COST	Operational cost as a function of active power generation	C
HR	Heat rate as a function of active power generation	HR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
ShutDown	Indicates if the generator has shut down between current time step and previous time step	ND
StartUp	Indicates if the generator has startup between current time step and previous time step	ND
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of FGEN.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAXDEF	Default maximum reactive power	QPOW
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
MinDownTimeDef	Default minimum down time, i.e. minimum duration a generator must be offline before it can start up. MinDownTime property is equal to MinDownTimeDef if no MinDownTime event is defined for a scenario	TIME
QMINDEF	Default minimum reactive power	QPOW
MinUpTimeDef	Default minimum up time, i.e. minimum duration a generator must be online before it can shut down. MinUpTime property is equal to MinUpTimeDef if no MinUpTime event is defined for a scenario	TIME
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
ShutDownPriceDef	Default price for shutting down a generator. ShutDownPrice property is equal to ShutDownPriceDef if no ShutDownPrice event is defined for a scenario	C
StartUpPriceDef	Default price for starting up a generator. StartUpPrice property is equal to StartUpPriceDef if no StartUpPrice event is defined for a scenario	C
VMSETDEF	Default voltage magnitude set point	PU
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of FGEN, which are applicable in ACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of FGEN, which are applicable in UACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
VMSETDEF	Default voltage magnitude set point	PU

Summary for the event-default properties of FGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
MinDownTimeDef	Default minimum down time, i.e. minimum duration a generator must be offline before it can start up. MinDownTime property is equal to MinDownTimeDef if no MinDownTime event is defined for a scenario	TIME
MinUpTimeDef	Default minimum up time, i.e. minimum duration a generator must be online before it can shut down. MinUpTime property is equal to MinUpTimeDef if no MinUpTime event is defined for a scenario	TIME
ShutDownPriceDef	Default price for shutting down a generator. ShutDownPrice property is equal to ShutDownPriceDef if no ShutDownPrice event is defined for a scenario	C
StartUpPriceDef	Default price for starting up a generator. StartUpPrice property is equal to StartUpPriceDef if no StartUpPrice event is defined for a scenario	C
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of FGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
VMSETDEF	Default voltage magnitude set point	PU
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of FGEN.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAX	Maximum reactive power	QPOW
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
MinDownTime	Minimum down time, i.e. minimum duration a generator must be offline before it can start up. MinDownTime property is equal to MinDownTimeDef if no MinDownTime event is defined for a scenario	TIME
QMIN	Minimum reactive power	QPOW
MinUpTime	Minimum up time, i.e. minimum duration a generator must be online before it can shut down. MinUpTime property is equal to MinUpTimeDef if no MinUpTime event is defined for a scenario	TIME
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
ShutDownPrice	Price for shutting down a generator. ShutDownPrice property is equal to ShutDownPriceDef if no ShutDownPrice event is defined for a scenario	C
StartUpPrice	Price for starting up a generator. StartUpPrice property is equal to StartUpPriceDef if no StartUpPrice event is defined for a scenario	C
VMSET	Voltage magnitude set point	PU
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of FGEN, which are applicable in ACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of FGEN, which are applicable in UACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of FGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
MinDownTime	Minimum down time, i.e. minimum duration a generator must be offline before it can start up. MinDownTime property is equal to MinDownTimeDef if no MinDownTime event is defined for a scenario	TIME
MinUpTime	Minimum up time, i.e. minimum duration a generator must be online before it can shut down. MinUpTime property is equal to MinUpTimeDef if no MinUpTime event is defined for a scenario	TIME
ShutDownPrice	Price for shutting down a generator. ShutDownPrice property is equal to ShutDownPriceDef if no ShutDownPrice event is defined for a scenario	C
StartUpPrice	Price for starting up a generator. StartUpPrice property is equal to StartUpPriceDef if no StartUpPrice event is defined for a scenario	C
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of FGEN, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of FGEN.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
FC0	Constant fuel consumption coefficient	NO
HR0	Constant heat rate coefficient	HR
FuelCurveType	Type of Fuel Curve object.
FuelName	Name of fuel the generator consumes	NO
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
FC1	Linear fuel consumption coefficient	NO
HR1	Linear heat rate coefficient	POWHR
EFFMAX	Maximum thermal efficiency of the generator	ND
EFFMIN	Minimum thermal efficiency of the generator	ND
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXN	Neutral reactance in per unit on the object base	PU
RRN	Neutral resistance in per unit on the object base	PU
NodeName	Name of node the external is connected to
NSEG	Specifies the number of piece-wise-linear segments quadratic fuel consumption curve will be divided into. Range 2 to 6. First segment represents line ranging from P=0 to P=PMIN	ND
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
FC2	Quadratic fuel consumption coefficient	NO
HR2	Quadratic heat rate coefficient	POW2HR
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of FGEN, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
HR0	Constant heat rate coefficient	HR
FuelCurveType	Type of Fuel Curve object.
FuelName	Name of fuel the generator consumes	NO
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
HR1	Linear heat rate coefficient	POWHR
EFFMAX	Maximum thermal efficiency of the generator	ND
EFFMIN	Minimum thermal efficiency of the generator	ND
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
HR2	Quadratic heat rate coefficient	POW2HR
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of FGEN, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
HR0	Constant heat rate coefficient	HR
FuelCurveType	Type of Fuel Curve object.
FuelName	Name of fuel the generator consumes	NO
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
HR1	Linear heat rate coefficient	POWHR
EFFMAX	Maximum thermal efficiency of the generator	ND
EFFMIN	Minimum thermal efficiency of the generator	ND
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
XXN	Neutral reactance in per unit on the object base	PU
RRN	Neutral resistance in per unit on the object base	PU
NodeName	Name of node the external is connected to
XXSE	Output reactance in per unit on the object base	PU
RRSE	Output resistance in per unit on the object base	PU
HR2	Quadratic heat rate coefficient	POW2HR
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of FGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
FC0	Constant fuel consumption coefficient	NO
FuelCurveType	Type of Fuel Curve object.
FuelName	Name of fuel the generator consumes	NO
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
FC1	Linear fuel consumption coefficient	NO
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
NSEG	Specifies the number of piece-wise-linear segments quadratic fuel consumption curve will be divided into. Range 2 to 6. First segment represents line ranging from P=0 to P=PMIN	ND
FC2	Quadratic fuel consumption coefficient	NO
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

Summary for the net-input properties of FGEN, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
HR0	Constant heat rate coefficient	HR
FuelCurveType	Type of Fuel Curve object.
FuelName	Name of fuel the generator consumes	NO
GenType	Specifies the generator type	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
HR1	Linear heat rate coefficient	POWHR
EFFMAX	Maximum thermal efficiency of the generator	ND
EFFMIN	Minimum thermal efficiency of the generator	ND
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
HR2	Quadratic heat rate coefficient	POW2HR
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Visible	If true, the object symbol will be visible in maps	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of FGEN.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of FGEN, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of FGEN, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of FGEN, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of FGEN, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of FGEN.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
MinDownTime	Constraint	Minimum downtime. Minimum: 0.	TIME
MinUpTime	Constraint	Minimum uptime. Minimum: 0.	TIME
OFF	State	Turn off facility, service or object.	NO
OFFINI	IniState	Time duration generator has been offline for before scenario start time. Minimum: 0.	TIME
ON	State	Turn on facility, service or object.	NO
ONINI	IniState	Time duration generator has been online for before scenario start time. Minimum: 0.	TIME
ONOFF	State	Enforce unit commitment decision by MIP-Solver.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
ShutDownPrice	Price	Shut down price. Minimum: 0.	C
StartUpPrice	Price	Startup price. Minimum: 0.	C
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of FGEN, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of FGEN, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of FGEN, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
MinDownTime	Constraint	Minimum downtime. Minimum: 0.	TIME
MinUpTime	Constraint	Minimum uptime. Minimum: 0.	TIME
OFF	State	Turn off facility, service or object.	NO
OFFINI	IniState	Time duration generator has been offline for before scenario start time. Minimum: 0.	TIME
ON	State	Turn on facility, service or object.	NO
ONINI	IniState	Time duration generator has been online for before scenario start time. Minimum: 0.	TIME
ONOFF	State	Enforce unit commitment decision by MIP-Solver.	NO
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
ShutDownPrice	Price	Shut down price. Minimum: 0.	C
StartUpPrice	Price	Startup price. Minimum: 0.	C
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of FGEN, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

The FuelConsumptionCurve has to be strictly convex. Non-convex curves (concave) can be managed clicking on the AdjustCurve option. By doing so, the input points are convexified. Please keep in mind that the first point is always P = 0, and not PMIN.

For the PMAXDEF property of a fuel generator, a value of 'Infinity' cannot be used in combination with the fuel consumption curve. Please ensure that PMAXDEF is set to a finite value whenever a fuel consumption curves is involved.

5.9. Wind generator (WIND)

An object for representing the electricity generator from a wind power plant generator. The electricity generation depends on the weather data (wind speed, temperature, etc.), the wind turbine power curve, and the wind properties (hub height, losses, etc.)

Summaries for the properties and events of WIND.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of WIND.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

Summary for the base-result properties of WIND, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW

Summary for the base-result properties of WIND, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW

Summary for the base-result properties of WIND, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC

Summary for the base-result properties of WIND, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of WIND.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
COST	Operational cost as a function of active power generation	C
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of WIND, which are applicable in ACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of WIND, which are applicable in UACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of WIND, which are applicable in DCUCOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of WIND, which are applicable in ACOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
COST	Operational cost as a function of active power generation	C
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of WIND.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAXDEF	Default maximum reactive power	QPOW
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
QSETDEF	Default total reactive power set point	QPOW
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of WIND, which are applicable in ACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
QSETDEF	Default total reactive power set point	QPOW

Summary for the event-default properties of WIND, which are applicable in UACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
QSETDEF	Default total reactive power set point	QPOW

Summary for the event-default properties of WIND, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of WIND, which are applicable in ACOPF.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
QSETDEF	Default total reactive power set point	QPOW
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of WIND.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAX	Maximum reactive power	QPOW
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of WIND, which are applicable in ACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of WIND, which are applicable in UACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of WIND, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of WIND, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of WIND.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
HubHeight	Hub height of the wind generator used for calculating the wind speed. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider
WTPCName	Name of wind turbine power curve object. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider. An exaustive list of wind tubine power curves is available in the user folder.

Summary for the net-input properties of WIND, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
HubHeight	Hub height of the wind generator used for calculating the wind speed. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider
WTPCName	Name of wind turbine power curve object. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider. An exaustive list of wind tubine power curves is available in the user folder.

Summary for the net-input properties of WIND, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
HubHeight	Hub height of the wind generator used for calculating the wind speed. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider
WTPCName	Name of wind turbine power curve object. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider. An exaustive list of wind tubine power curves is available in the user folder.

Summary for the net-input properties of WIND, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
HubHeight	Hub height of the wind generator used for calculating the wind speed. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider
WTPCName	Name of wind turbine power curve object. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider. An exaustive list of wind tubine power curves is available in the user folder.

Summary for the net-input properties of WIND, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
HubHeight	Hub height of the wind generator used for calculating the wind speed. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	H
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider
WTPCName	Name of wind turbine power curve object. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider. An exaustive list of wind tubine power curves is available in the user folder.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of WIND.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of WIND, which are applicable in ACPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of WIND, which are applicable in UACPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of WIND, which are applicable in DCUCOPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of WIND, which are applicable in ACOPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of WIND.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of WIND, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of WIND, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of WIND, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of WIND, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

5.10. Solar generator (PV)

An object for representing the electricity generator from a solar power plant generator. The electricity generation depends on the weather data (global horizontal irradiance, diffuse irradiance, etc.), and the solar plant properties (tilt angle, losses, etc.).

Summaries for the properties and events of PV.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of PV.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

Summary for the base-result properties of PV, which are applicable in ACPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW

Summary for the base-result properties of PV, which are applicable in UACPF.
Extension	Description	UnitType
P	Total active power	PPOW
IAPHASEA	Angle of phase A current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEB	Angle of phase B current directing to node (directing away from node, if it is demand)	ANGLE
IAPHASEC	Angle of phase C current directing to node (directing away from node, if it is demand)	ANGLE
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
IPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand), with network per unit base	PU
IPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand), with network per unit base	PU
Q	Total reactive power	QPOW

Summary for the base-result properties of PV, which are applicable in DCUCOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC

Summary for the base-result properties of PV, which are applicable in ACOPF.
Extension	Description	UnitType
P	Total active power	PPOW
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
Q	Total reactive power	QPOW
PSHDW	Shadow price for maximum active power limit on the external	NRGPRC
QSHDW	Shadow price for reactive power hard limits	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of PV.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
COST	Operational cost as a function of active power generation	C
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
IMAX	Maximum current magnitude in network per-unit system	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of PV, which are applicable in ACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of PV, which are applicable in UACPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
PPHASEA	Active power in phase A	PPOW
PPHASEB	Active power in phase B	PPOW
PPHASEC	Active power in phase C	PPOW
IMPHASEA	Magnitude of phase A current directing to node (directing away from node, if it is demand)	CURR
IMPHASEB	Magnitude of phase B current directing to node (directing away from node, if it is demand)	CURR
IMPHASEC	Magnitude of phase C current directing to node (directing away from node, if it is demand)	CURR
IMAX	Maximum current magnitude in network per-unit system	PU
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
IANEUTRAL	Angle of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	ANGLE
INEUTRAL	Magnitude of current directing from ground to wye-connected neutral point (directing to ground, if it is demand)	CURR
VAPHASEATOB	Voltage angle of Phase A-to-B, line-to-line voltage	ANGLE
VMPHASEATOB	Magnitude of Phase A-to-B line-to-line voltage	VOLT
VPUPHASEATOB	Voltage magnitude of Phase A-to-B, line-to-line voltage in per unit	PU
VAPHASEA	Voltage angle of Phase A, line-to-neutral voltage	ANGLE
VMPHASEA	Magnitude of Phase A line-to-neutral voltage	VOLT
VPUPHASEA	Voltage magnitude of Phase A, line-to-neutral voltage in per unit	PU
VAPHASEBTOC	Voltage angle of Phase B-to-C, line-to-line voltage	ANGLE
VMPHASEBTOC	Magnitude of Phase B-to-C line-to-line voltage	VOLT
VPUPHASEBTOC	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEB	Voltage angle of Phase B, line-to-neutral voltage	ANGLE
VMPHASEB	Magnitude of Phase B line-to-neutral voltage	VOLT
VPUPHASEB	Voltage magnitude of Phase B, line-to-neutral voltage in per unit	PU
VAPHASECTOA	Voltage angle of Phase C-to-A, line-to-line voltage	ANGLE
VMPHASECTOA	Magnitude of Phase C-to-A line-to-line voltage	VOLT
VPUPHASECTOA	Voltage magnitude of Phase B-to-C, line-to-line voltage in per unit	PU
VAPHASEC	Voltage angle of Phase C, line-to-neutral voltage	ANGLE
VMPHASEC	Magnitude of Phase C line-to-neutral voltage	VOLT
VPUPHASEC	Voltage magnitude of Phase C, line-to-neutral voltage in per unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
QPHASEA	Reactive power in phase A	QPOW
QPHASEB	Reactive power in phase B	QPOW
QPHASEC	Reactive power in phase C	QPOW
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

Summary for the derived-result properties of PV, which are applicable in DCUCOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
TOTCOSTRATE	Total cost per time for operating the generator. For FGEN it is calculated as the sum of TOTVOMRATE and FuelCostRate (it does not include StartUpCostRate and ShutDownCostRate). For all other generators TOTCOSTRATE is equal to TOTVOMRATE	PRCDOT
VA	Voltage Angle	ANGLE

Summary for the derived-result properties of PV, which are applicable in ACOPF.
Extension	Description	UnitType
PNS	Difference between scheduled and delivered active power. Calculated as the sum of PSET minus P	PPOW
COST	Operational cost as a function of active power generation	C
VMAX	Maximum Voltage Magnitude in network per-unit	PU
VMIN	Minimum Voltage Magnitude in network per-unit	PU
RampRate	Active power ramp rate. Change in active power per time between two consecutive time steps	RAMP
VA	Voltage Angle	ANGLE
VM	Voltage Magnitude (for UACPF, the average of line-to-line voltage magnitudes of available phases at the node)	VOLT
VPU	Voltage magnitude per unit	PU

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of PV.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAXDEF	Default maximum reactive power	QPOW
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
QSETDEF	Default total reactive power set point	QPOW
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of PV, which are applicable in ACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
QSETDEF	Default total reactive power set point	QPOW

Summary for the event-default properties of PV, which are applicable in UACPF.
Extension	Description	UnitType
PFSETDEF	Default active power slack participation factor set point (does not apply in DCUCOPF). If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
QMINDEF	Default minimum reactive power	QPOW
QSETDEF	Default total reactive power set point	QPOW

Summary for the event-default properties of PV, which are applicable in DCUCOPF.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
MaxDownRampDef	Default maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. It defines the maximum rate of change (decrease) of the object between two consecutives timesteps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRampDef	Default maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. It defines the maximum rate of change (increase) of the object between two consecutives timesteps. MaxUpRamp property is equal to MaxUpRampDef if no MaxUpRamp event is defined for a scenario	RAMP
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-default properties of PV, which are applicable in ACOPF.
Extension	Description	UnitType
PSETDEF	Default total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRCDEF	Default penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0DEF	Default constant coefficient of operational cost	C
C1DEF	Default linear coefficient of operational cost	NRGPRC
PMAXDEF	Default maximum active power also used to calculate name plate capacity (NCAP). PMAX property is equal to PMAXDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRCDEF	Default penalty price for exceeding the maximum active power (PMAX). The default event defined at the network level can be overwritten by a PMAXPRC event at the scenario level. Penalty is calculated as (P-PMAX) * PMAXPRCDEF	NRGPRC
QMAXDEF	Default maximum reactive power	QPOW
PMINDEF	Default minimum active power. PMIN property is equal to PMINDEF if no PMIN event is defined for a scenario	PPOW
PMINPRCDEF	Default penalty price for exceeding the minimum active power (PMIN). The default event defined at the network level can be overwritten by a PMINPRC event at the scenario level. Penalty is calculated as (PMIN-P) * PMINPRCDEF	NRGPRC
QMINDEF	Default minimum reactive power	QPOW
C2DEF	Default quadratic coefficient of operational cost	NRG2PRC
QSETDEF	Default total reactive power set point	QPOW
VOMPriceDef	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of PV.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
QMAX	Maximum reactive power	QPOW
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of PV, which are applicable in ACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of PV, which are applicable in UACPF.
Extension	Description	UnitType
PFSET	Active power slack participation factor set point. If participation factors are not provided (=0), slack will be distributed according to generator size	ND
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
QMIN	Minimum reactive power	QPOW
QREF	Reactive power reference	QPOW
QSET	Total reactive power set point	QPOW
VMSET	Voltage magnitude set point	PU

Summary for the event-value properties of PV, which are applicable in DCUCOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
MaxDownRamp	Maximum downward ramp rate for active power. It describes the rate at which the active power can decrease between two consecutive time steps. MaxDownRamp property is equal to MaxDownRampDef if no MaxDownRamp event is defined for a scenario	RAMP
MaxUpRamp	Maximum upward ramp rate for active power. It describes the rate at which the active power can increase between two consecutive time steps. MaxUpRamp property is equal to MaxDownUpDef if no MaxDownRamp event is defined for a scenario	RAMP
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

Summary for the event-value properties of PV, which are applicable in ACOPF.
Extension	Description	UnitType
PREF	Active power reference which can be used for comparing results. It has no effect on the scenario results. It is the event value of the passive event PREF	PPOW
PSET	Total active power set point. PSET is equal to PSETDEF if no PSET event is defined for a scenario	PPOW
PSETPRC	Penalty price for not meeting (curtailing) active power set point (PSETDEF). PSETPRC is equal to PSETPRCDEF if no PSETPRC event is defined for a scenario. Penalty is calculated as (PSET-P) * PSETPRC	NRGPRC
C0	Constant coefficient of operational cost	C
C1	Linear coefficient of operational cost	NRGPRC
PMAX	Maximum active power. Is the event value property of the PMAX event. PMAX is equal to PSETDEF if no PMAX event is defined for a scenario	PPOW
PMAXPRC	Penalty price for maximum active power. If applied, it overwrites the PMAXPRCDEF value defined at the network level	NRGPRC
QMAX	Maximum reactive power	QPOW
PMIN	Minimum active power. If applied, it overwrites the PMINDEF value defined at the network level	PPOW
PMINPRC	Penalty price for minimum active power. If applied, it overwrites the PMINPRCDEF value defined at the network level	NRGPRC
QMIN	Minimum reactive power	QPOW
C2	Quadratic coefficient of operational cost	NRG2PRC
QREF	Reactive power reference	QPOW
VOMPrice	Default variable operational and maintenance price per produced energy. VOMPrice property is equal to VOMPriceDef if no VOMPrice event is defined for a scenario	NRGPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of PV.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
ArrayType	Tilt system of the array of the solar generator. It describes whether the PV modules are fixed, or they move to track the movement of the sun across the sky with one or two axes of rotation. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Azimuth	Azimuth angle of the solar generator, North = 0 [°], East = 90 [°], South = 180 [°], West = 270 [°]. For a fixed array, it is the angle clockwise from true north describing the direction that the array faces. For an array with one-axis tracking, it is the angle clockwise from true north of the axis of rotation. It does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
DCACRatio	DC-AC power ratio of the solar generator. It is the ratio of the array’s DC rated size to the inverter’s AC rated size. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ND
GENPHASES	Identifies if the generator is three-phase or single-phase, if it is a single-phase, then to which phase it is connected, valid values are A, B, C, or ABC	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
InvEff	Inverter efficiency of the solar generator. Defined as the inverter’s rated AC power output divided by its rated DC power output. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
IMAXPU	Maximum current magnitude in per-unit based on the apparent power and voltage ratings	PU
VMAXPU	Maximum voltage magnitude in per-unit based on the rated voltage	PU
VMINPU	Minimum voltage magnitude in per-unit based on the rated voltage	PU
ModuleType	Type of solar modules of the solar generator. Approximate nominal efficiencies are 19% for standard, 21% for premium, and 18% for thin film. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Tilt	Tilt angle of the solar generator relative to horizon, 0 [°] is horizontal 90 [°] is vertical. For a fixed array, it is the angle from horizontal of the array where 0° = horizontal, and 90° = vertical. For arrays with one-axis tracking, it is the angle from horizontal of the tracking axis. The tilt angle does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider

Summary for the net-input properties of PV, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
ArrayType	Tilt system of the array of the solar generator. It describes whether the PV modules are fixed, or they move to track the movement of the sun across the sky with one or two axes of rotation. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Azimuth	Azimuth angle of the solar generator, North = 0 [°], East = 90 [°], South = 180 [°], West = 270 [°]. For a fixed array, it is the angle clockwise from true north describing the direction that the array faces. For an array with one-axis tracking, it is the angle clockwise from true north of the axis of rotation. It does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
DCACRatio	DC-AC power ratio of the solar generator. It is the ratio of the array’s DC rated size to the inverter’s AC rated size. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
InvEff	Inverter efficiency of the solar generator. Defined as the inverter’s rated AC power output divided by its rated DC power output. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
ModuleType	Type of solar modules of the solar generator. Approximate nominal efficiencies are 19% for standard, 21% for premium, and 18% for thin film. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Tilt	Tilt angle of the solar generator relative to horizon, 0 [°] is horizontal 90 [°] is vertical. For a fixed array, it is the angle from horizontal of the array where 0° = horizontal, and 90° = vertical. For arrays with one-axis tracking, it is the angle from horizontal of the tracking axis. The tilt angle does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider

Summary for the net-input properties of PV, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
ArrayType	Tilt system of the array of the solar generator. It describes whether the PV modules are fixed, or they move to track the movement of the sun across the sky with one or two axes of rotation. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Azimuth	Azimuth angle of the solar generator, North = 0 [°], East = 90 [°], South = 180 [°], West = 270 [°]. For a fixed array, it is the angle clockwise from true north describing the direction that the array faces. For an array with one-axis tracking, it is the angle clockwise from true north of the axis of rotation. It does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
DCACRatio	DC-AC power ratio of the solar generator. It is the ratio of the array’s DC rated size to the inverter’s AC rated size. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ND
GENPHASES	Identifies if the generator is three-phase or single-phase, if it is a single-phase, then to which phase it is connected, valid values are A, B, C, or ABC	NO
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
InvEff	Inverter efficiency of the solar generator. Defined as the inverter’s rated AC power output divided by its rated DC power output. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
IMAXPU	Maximum current magnitude in per-unit based on the apparent power and voltage ratings	PU
VMAXPU	Maximum voltage magnitude in per-unit based on the rated voltage	PU
VMINPU	Minimum voltage magnitude in per-unit based on the rated voltage	PU
ModuleType	Type of solar modules of the solar generator. Approximate nominal efficiencies are 19% for standard, 21% for premium, and 18% for thin film. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDS	Rated apparent power, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Apparent Power will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	SPOW
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Tilt	Tilt angle of the solar generator relative to horizon, 0 [°] is horizontal 90 [°] is vertical. For a fixed array, it is the angle from horizontal of the array where 0° = horizontal, and 90° = vertical. For arrays with one-axis tracking, it is the angle from horizontal of the tracking axis. The tilt angle does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider

Summary for the net-input properties of PV, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
ArrayType	Tilt system of the array of the solar generator. It describes whether the PV modules are fixed, or they move to track the movement of the sun across the sky with one or two axes of rotation. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Azimuth	Azimuth angle of the solar generator, North = 0 [°], East = 90 [°], South = 180 [°], West = 270 [°]. For a fixed array, it is the angle clockwise from true north describing the direction that the array faces. For an array with one-axis tracking, it is the angle clockwise from true north of the axis of rotation. It does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
DCACRatio	DC-AC power ratio of the solar generator. It is the ratio of the array’s DC rated size to the inverter’s AC rated size. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
InvEff	Inverter efficiency of the solar generator. Defined as the inverter’s rated AC power output divided by its rated DC power output. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
ModuleType	Type of solar modules of the solar generator. Approximate nominal efficiencies are 19% for standard, 21% for premium, and 18% for thin film. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Tilt	Tilt angle of the solar generator relative to horizon, 0 [°] is horizontal 90 [°] is vertical. For a fixed array, it is the angle from horizontal of the array where 0° = horizontal, and 90° = vertical. For arrays with one-axis tracking, it is the angle from horizontal of the tracking axis. The tilt angle does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider

Summary for the net-input properties of PV, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
ArrayType	Tilt system of the array of the solar generator. It describes whether the PV modules are fixed, or they move to track the movement of the sun across the sky with one or two axes of rotation. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Azimuth	Azimuth angle of the solar generator, North = 0 [°], East = 90 [°], South = 180 [°], West = 270 [°]. For a fixed array, it is the angle clockwise from true north describing the direction that the array faces. For an array with one-axis tracking, it is the angle clockwise from true north of the axis of rotation. It does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
CALCDFLT	Calculate default values for maximum ramp rate (MaxUpRampDef and MaxDownRampDef), and (when applicable) startup time (MinUpTimeDef and MinDownTimeDef), generator capability curve (GCC), heat rate curve (HR0, HR1, and HR2)
DCACRatio	DC-AC power ratio of the solar generator. It is the ratio of the array’s DC rated size to the inverter’s AC rated size. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ND
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
InvEff	Inverter efficiency of the solar generator. Defined as the inverter’s rated AC power output divided by its rated DC power output. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Lat	Latitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
Long	Longitude of the object based on WGS84 Datum. Used only to retrieve weather resource data from external data providers for PV and WIND objects	LATLONG
ModuleType	Type of solar modules of the solar generator. Approximate nominal efficiencies are 19% for standard, 21% for premium, and 18% for thin film. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NodeName	Name of node the external is connected to
RATEDV	Rated line-to-line voltage, assuming balanced three-phase object. If its value is NaN, which is the default, the network Base Voltage will be taken. It is used in the network per unit calculations. To change the value of a property to its default, right-click on the property and select “Set to the default value"	VOLT
Tilt	Tilt angle of the solar generator relative to horizon, 0 [°] is horizontal 90 [°] is vertical. For a fixed array, it is the angle from horizontal of the array where 0° = horizontal, and 90° = vertical. For arrays with one-axis tracking, it is the angle from horizontal of the tracking axis. The tilt angle does not apply to arrays with two-axis tracking. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	ANGLE
LOSSES	Total system losses. Considered only when the generation profile is derived from the weather resource data retrieved from a data provider	PC
Visible	If true, the object symbol will be visible in maps	NO
WDFile	Path to weather data file. A folder named "WeatherDataFile" is created after retrieving data from an external data provider

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of PV.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of PV, which are applicable in ACPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of PV, which are applicable in UACPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of PV, which are applicable in DCUCOPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of PV, which are applicable in ACOPF.
Extension	Description	UnitType
GenType	Specifies the generator type	NO
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the events of PV.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of PV, which are applicable in ACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of PV, which are applicable in UACPF.
Parameter	Type	Description	UnitType
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PFSET	SetPoint	Active power compensation factor set point. Minimum: 0.	ND
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
QSET	SetPoint	Total reactive power set point.	QPOW
VMSET	SetPoint	Voltage magnitude set point. Minimum: 0. Maximum: 100.	PU

Summary for the events of PV, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
MaxDownRamp	Constraint	Maximum downward ramp rate. Minimum: 0.	RAMP
MaxUpRamp	Constraint	Maximum upward ramp rate. Minimum: 0.	RAMP
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PINI	IniState	Initial active power generation. Minimum: 0.	PPOW
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

Summary for the events of PV, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
C0	Coefficient	Constant coefficient of operational cost. Minimum: 0.	C
C1	Coefficient	Linear coefficient of operational cost. Minimum: 0.	NRGPRC
C2	Coefficient	Quadratic coefficient of operational cost. Minimum: 0.	NRG2PRC
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
PMAX	Constraint	Maximum active power. Minimum: 0.	PPOW
PMAXPRC	PenaltyPrice	Penalty price for maximum active power violation. Minimum: 0.	NRGPRC
PMIN	Constraint	Minimum active power. Minimum: 0.	PPOW
PMINPRC	PenaltyPrice	Penalty price for minimum active power violation. Minimum: 0.	NRGPRC
PREF	Reference	Active power reference. Minimum: 0.	PPOW
PSET	SetPoint	Total active power set point. Minimum: 0.	PPOW
PSETPRC	PenaltyPrice	Penalty price for not meeting (curtailing) active power set point . Minimum: 0.	NRGPRC
QMAX	Constraint	Maximum reactive power.	QPOW
QMIN	Constraint	Minimum reactive power.	QPOW
QREF	Reference	Reactive power reference.	QPOW
VOMPrice	Price	Variable operational and maintenance price.	NRGPRC

6. Fuel (FUEL)

A fuel object requires a connection to a fuel generator. The same object can be connected to several fuel generators.

Summaries for the properties and events of FUEL.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of FUEL.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of FUEL, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of FUEL, which are applicable in UACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of FUEL, which are applicable in DCUCOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of FUEL, which are applicable in ACOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

ALL
DCUCOPF

Summary for the derived-result properties of FUEL.
Extension	Description	UnitType
CO2RATE	Carbon dioxide emission rate	EMDOT
FuelCostRate	Total fuel cost rate	PRCDOT
F	Fuel consumption rate	NO
NOXRATE	Nitrogen oxide emission rate	EMDOT
SO2RATE	Sulfur dioxide emission rate	EMDOT

Summary for the derived-result properties of FUEL, which are applicable in DCUCOPF.
Extension	Description	UnitType
CO2RATE	Carbon dioxide emission rate	EMDOT
FuelCostRate	Total fuel cost rate	PRCDOT
F	Fuel consumption rate	NO
NOXRATE	Nitrogen oxide emission rate	EMDOT
SO2RATE	Sulfur dioxide emission rate	EMDOT

ALL
DCUCOPF

Summary for the event-default properties of FUEL.
Extension	Description	UnitType
FuelPriceDef	Default fuel price	NO

Summary for the event-default properties of FUEL, which are applicable in DCUCOPF.
Extension	Description	UnitType
FuelPriceDef	Default fuel price	NO

ALL
DCUCOPF

Summary for the event-value properties of FUEL.
Extension	Description	UnitType
FAVG	Average fuel consumption rate over a period of 24 hours using the TimeOfDay of the scenario start time as the start of the period	NO
FuelPrice	Price per consumed fuel unit	NO
FMAX	Maximum fuel consumption rate	NO

Summary for the event-value properties of FUEL, which are applicable in DCUCOPF.
Extension	Description	UnitType
FAVG	Average fuel consumption rate over a period of 24 hours using the TimeOfDay of the scenario start time as the start of the period	NO
FuelPrice	Price per consumed fuel unit	NO
FMAX	Maximum fuel consumption rate	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of FUEL.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CO2	CO2 emission per fuel unit	NO
FuelUnit	Fuel unit of specified fuel unit type
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NOX	NOx emission per fuel unit	NO
SO2	SO2 emission per fuel unit	NO

Summary for the net-input properties of FUEL, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
FuelUnit	Fuel unit of specified fuel unit type
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of FUEL, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
FuelUnit	Fuel unit of specified fuel unit type
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of FUEL, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
CO2	CO2 emission per fuel unit	NO
FuelUnit	Fuel unit of specified fuel unit type
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
NOX	NOx emission per fuel unit	NO
SO2	SO2 emission per fuel unit	NO

Summary for the net-input properties of FUEL, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
FuelUnit	Fuel unit of specified fuel unit type
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of FUEL.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of FUEL, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of FUEL, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of FUEL, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of FUEL, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
DCUCOPF

Summary for the events of FUEL.
Parameter	Type	Description	UnitType
FAVG	SetPoint	Average fuel consumption rate.	NO
FMAX	Constraint	Maximum fuel consumption rate.	NO
FuelPrice	Price	Price per consumed fuel unit.	NO
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO

Summary for the events of FUEL, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
FAVG	SetPoint	Average fuel consumption rate.	NO
FMAX	Constraint	Maximum fuel consumption rate.	NO
FuelPrice	Price	Price per consumed fuel unit.	NO
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO

7. Hydro plant (HYDP)

A hydropower plant consists of a water reservoir connected to one or more hydro generators. Water is modeled to flow in the hydropower plant object either from inflow (rain, etc.), water turbinated by another hydropower plant, water pumped by a hydro generator, or spillage from a hydropower plant. The water outflow is modeled as water turbinated to another hydropower plant, turbinated to generate electricity, spilled with (spill) and without penalties (outflow).

Summaries for the properties and events of HYDP.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of HYDP.
Extension	Description	UnitType
BYPASS	Total flow bypassing turbines through hydro plant	HQVOL
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
VOL	Reservoir volume	VOL
SPILL	Total spilled flow through hydro power plant	HQVOL
TURB	Total turbinated flow through hydro plant	HQVOL

Summary for the base-result properties of HYDP, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of HYDP, which are applicable in UACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of HYDP, which are applicable in DCUCOPF.
Extension	Description	UnitType
BYPASS	Total flow bypassing turbines through hydro plant	HQVOL
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
VOL	Reservoir volume	VOL
SPILL	Total spilled flow through hydro power plant	HQVOL
TURB	Total turbinated flow through hydro plant	HQVOL

Summary for the base-result properties of HYDP, which are applicable in ACOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

ALL
DCUCOPF

Summary for the derived-result properties of HYDP.
Extension	Description	UnitType
TURBMIN	Minimum total turbinated flow through hydro power plant	HQVOL

Summary for the derived-result properties of HYDP, which are applicable in DCUCOPF.
Extension	Description	UnitType
TURBMIN	Minimum total turbinated flow through hydro power plant	HQVOL

ALL
DCUCOPF

Summary for the event-default properties of HYDP.
Extension	Description	UnitType
INFLOWDEF	Default inflow to hydro power plant	HQVOL
BYPASSMAXDEF	Default maximum total flow bypassing turbines through hydro plant	HQVOL
BYPASSMAXPRCDEF	Default maximum total flow bypassing turbine through hydro plant penalty price	VOLPRC
PUMPMAXDEF	Default maximum total pumped flow through hydro plant	HQVOL
PUMPMAXPRCDEF	Default maximum total pumped flow through hydro plant penalty price	VOLPRC
VOLMAXDEF	Default maximum reservoir volume	VOL
VOLMAXPRCDEF	Default maximum reservoir volume penalty price	VOLPRC
SPILLMAXDEF	Default maximum total spilled flow through hydro power plant	HQVOL
SPILLMAXPRCDEF	Default maximum total spilled flow through hydro power plant penalty price	VOLPRC
TURBMAXDEF	Default maximum total turbinated flow through hydro power plant	HQVOL
TURBMAXPRCDEF	Default maximum total turbinated flow through hydro power plant penalty price	VOLPRC
VOLMINDEF	Default minimum reservoir volume	VOL
VOLMINPRCDEF	Default minimum reservoir volume penalty price	VOLPRC
SPILLMINDEF	Default minimum total spilled flow through hydro power plant	HQVOL
SPILLMINPRCDEF	Default minimum total spilled flow through hydro power plant penalty price	VOLPRC
OUTFLOWDEF	Default flow rate leaving the hydro power plant for irrigation and other purposes	HQVOL
VOLSETPRCDEF	Default penalty price for curtailing reservoir volume set point	VOLPRC
SPILLPRCDEF	Default penalty price for spilled flow	VOLPRC

Summary for the event-default properties of HYDP, which are applicable in DCUCOPF.
Extension	Description	UnitType
INFLOWDEF	Default inflow to hydro power plant	HQVOL
BYPASSMAXDEF	Default maximum total flow bypassing turbines through hydro plant	HQVOL
BYPASSMAXPRCDEF	Default maximum total flow bypassing turbine through hydro plant penalty price	VOLPRC
PUMPMAXDEF	Default maximum total pumped flow through hydro plant	HQVOL
PUMPMAXPRCDEF	Default maximum total pumped flow through hydro plant penalty price	VOLPRC
VOLMAXDEF	Default maximum reservoir volume	VOL
VOLMAXPRCDEF	Default maximum reservoir volume penalty price	VOLPRC
SPILLMAXDEF	Default maximum total spilled flow through hydro power plant	HQVOL
SPILLMAXPRCDEF	Default maximum total spilled flow through hydro power plant penalty price	VOLPRC
TURBMAXDEF	Default maximum total turbinated flow through hydro power plant	HQVOL
TURBMAXPRCDEF	Default maximum total turbinated flow through hydro power plant penalty price	VOLPRC
VOLMINDEF	Default minimum reservoir volume	VOL
VOLMINPRCDEF	Default minimum reservoir volume penalty price	VOLPRC
SPILLMINDEF	Default minimum total spilled flow through hydro power plant	HQVOL
SPILLMINPRCDEF	Default minimum total spilled flow through hydro power plant penalty price	VOLPRC
OUTFLOWDEF	Default flow rate leaving the hydro power plant for irrigation and other purposes	HQVOL
VOLSETPRCDEF	Default penalty price for curtailing reservoir volume set point	VOLPRC
SPILLPRCDEF	Default penalty price for spilled flow	VOLPRC

ALL
DCUCOPF

Summary for the event-value properties of HYDP.
Extension	Description	UnitType
INFLOW	Inflow to hydro power plant	HQVOL
BYPASSMAX	Maximum total flow bypassing turbines through hydro plant	HQVOL
BYPASSMAXPRC	Maximum total flow bypassing turbine through hydro plant penalty price	VOLPRC
PUMPMAX	Maximum total pumped flow through hydro plant	HQVOL
PUMPMAXPRC	Maximum total pumped flow through hydro plant penalty price	VOLPRC
VOLMAX	Maximum reservoir volume	VOL
VOLMAXPRC	Maximum reservoir volume penalty price	VOLPRC
SPILLMAX	Maximum total spilled flow through hydro power plant	HQVOL
SPILLMAXPRC	Maximum total spilled flow through hydro power plant penalty price	VOLPRC
TURBMAX	Maximum total turbinated flow through hydro power plant	HQVOL
TURBMAXPRC	Maximum total turbinated flow through hydro power plant penalty price	VOLPRC
VOLMIN	Minimum reservoir volume	VOL
VOLMINPRC	Minimum reservoir volume penalty price	VOLPRC
SPILLMIN	Minimum total spilled flow through hydro power plant	HQVOL
SPILLMINPRC	Minimum total spilled flow through hydro power plant penalty price	VOLPRC
OUTFLOW	Flow rate leaving the hydro power plant for irrigation and other purposes	HQVOL
VOLSET	Reservoir volume set point	VOL
VOLSETPRC	Penalty price for curtailing reservoir volume set point	VOLPRC
SPILLPRC	Penalty price for spilled flow	VOLPRC

Summary for the event-value properties of HYDP, which are applicable in DCUCOPF.
Extension	Description	UnitType
INFLOW	Inflow to hydro power plant	HQVOL
BYPASSMAX	Maximum total flow bypassing turbines through hydro plant	HQVOL
BYPASSMAXPRC	Maximum total flow bypassing turbine through hydro plant penalty price	VOLPRC
PUMPMAX	Maximum total pumped flow through hydro plant	HQVOL
PUMPMAXPRC	Maximum total pumped flow through hydro plant penalty price	VOLPRC
VOLMAX	Maximum reservoir volume	VOL
VOLMAXPRC	Maximum reservoir volume penalty price	VOLPRC
SPILLMAX	Maximum total spilled flow through hydro power plant	HQVOL
SPILLMAXPRC	Maximum total spilled flow through hydro power plant penalty price	VOLPRC
TURBMAX	Maximum total turbinated flow through hydro power plant	HQVOL
TURBMAXPRC	Maximum total turbinated flow through hydro power plant penalty price	VOLPRC
VOLMIN	Minimum reservoir volume	VOL
VOLMINPRC	Minimum reservoir volume penalty price	VOLPRC
SPILLMIN	Minimum total spilled flow through hydro power plant	HQVOL
SPILLMINPRC	Minimum total spilled flow through hydro power plant penalty price	VOLPRC
OUTFLOW	Flow rate leaving the hydro power plant for irrigation and other purposes	HQVOL
VOLSET	Reservoir volume set point	VOL
VOLSETPRC	Penalty price for curtailing reservoir volume set point	VOLPRC
SPILLPRC	Penalty price for spilled flow	VOLPRC

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of HYDP.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
TURBMINDEF	Default minimum total turbinated flow through hydro power plant	HQVOL
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
SpillToName	Name of hydro power plant receiving spilled water flow
TurbToName	Name of hydro power plant receiving turbinated water flow

Summary for the net-input properties of HYDP, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of HYDP, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of HYDP, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
TURBMINDEF	Default minimum total turbinated flow through hydro power plant	HQVOL
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
SpillToName	Name of hydro power plant receiving spilled water flow
TurbToName	Name of hydro power plant receiving turbinated water flow

Summary for the net-input properties of HYDP, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of HYDP.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of HYDP, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of HYDP, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of HYDP, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of HYDP, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
DCUCOPF

Summary for the events of HYDP.
Parameter	Type	Description	UnitType
BYPASSMAX	Constraint	Maximum bypass flow. Minimum: 0.	HQVOL
BYPASSMAXPRC	PenaltyPrice	Penalty price for maximum bypass flow. Minimum: 0.	VOLPRC
INFLOW	SetPoint	Inflow to hydro plants from rivers and other sources. Minimum: 0.	HQVOL
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
OUTFLOW	SetPoint	Outflow leaving the hydro plant. Minimum: 0.	HQVOL
PUMPMAX	Constraint	Maximum pumped flow. Minimum: 0.	HQVOL
PUMPMAXPRC	PenaltyPrice	Penalty price for maximum pumped flow. Minimum: 0.	VOLPRC
SPILLMAX	Constraint	Maximum spilled flow. Minimum: 0.	HQVOL
SPILLMAXPRC	PenaltyPrice	Penalty price for maximum spilled flow. Minimum: 0.	VOLPRC
SPILLMIN	Constraint	Minimum spilled flow. Minimum: 0.	HQVOL
SPILLMINPRC	PenaltyPrice	Penalty price for minimum spilled flow. Minimum: 0.	VOLPRC
SPILLPRC	PenaltyPrice	Penalty price for spilled flow. Minimum: 0.	VOLPRC
TURBMAX	Constraint	Maximum turbinated flow. Minimum: 0.	HQVOL
TURBMAXPRC	PenaltyPrice	Penalty price for maximum turbinated flow. Minimum: 0.	VOLPRC
VOLMAX	Constraint	Maximum reservoir volume. Minimum: 0.	VOL
VOLMAXPRC	PenaltyPrice	Penalty price for maximum reservoir volume. Minimum: 0.	VOLPRC
VOLMIN	Constraint	Minimum reservoir volume. Minimum: 0.	VOL
VOLMINPRC	PenaltyPrice	Penalty price for minimum reservoir volume. Minimum: 0.	VOLPRC
VOLSET	StorageSetPoint	Reservoir volume set point. Minimum: 0.	VOL
VOLSETPRC	PenaltyPrice	Penalty price for curtailment of reservoir volume set point . Minimum: 0.	VOLPRC

Summary for the events of HYDP, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
BYPASSMAX	Constraint	Maximum bypass flow. Minimum: 0.	HQVOL
BYPASSMAXPRC	PenaltyPrice	Penalty price for maximum bypass flow. Minimum: 0.	VOLPRC
INFLOW	SetPoint	Inflow to hydro plants from rivers and other sources. Minimum: 0.	HQVOL
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
OUTFLOW	SetPoint	Outflow leaving the hydro plant. Minimum: 0.	HQVOL
PUMPMAX	Constraint	Maximum pumped flow. Minimum: 0.	HQVOL
PUMPMAXPRC	PenaltyPrice	Penalty price for maximum pumped flow. Minimum: 0.	VOLPRC
SPILLMAX	Constraint	Maximum spilled flow. Minimum: 0.	HQVOL
SPILLMAXPRC	PenaltyPrice	Penalty price for maximum spilled flow. Minimum: 0.	VOLPRC
SPILLMIN	Constraint	Minimum spilled flow. Minimum: 0.	HQVOL
SPILLMINPRC	PenaltyPrice	Penalty price for minimum spilled flow. Minimum: 0.	VOLPRC
SPILLPRC	PenaltyPrice	Penalty price for spilled flow. Minimum: 0.	VOLPRC
TURBMAX	Constraint	Maximum turbinated flow. Minimum: 0.	HQVOL
TURBMAXPRC	PenaltyPrice	Penalty price for maximum turbinated flow. Minimum: 0.	VOLPRC
VOLMAX	Constraint	Maximum reservoir volume. Minimum: 0.	VOL
VOLMAXPRC	PenaltyPrice	Penalty price for maximum reservoir volume. Minimum: 0.	VOLPRC
VOLMIN	Constraint	Minimum reservoir volume. Minimum: 0.	VOL
VOLMINPRC	PenaltyPrice	Penalty price for minimum reservoir volume. Minimum: 0.	VOLPRC
VOLSET	StorageSetPoint	Reservoir volume set point. Minimum: 0.	VOL
VOLSETPRC	PenaltyPrice	Penalty price for curtailment of reservoir volume set point . Minimum: 0.	VOLPRC

8. Ancillary service (ASVC)

Ancillary services represent the precautionary measures taken to ensure reliability of an electric network in the event of a disturbance (e.g., transmission line outage, generator outage, etc.). The ancillary service object is valid only in a DCUCOPF scenario.

Summaries for the properties and events of ASVC.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of ASVC.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for minimum ancillary service requirement	NRGPRC
ValCurt	Total curtailment of service requirement	NO

Summary for the base-result properties of ASVC, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of ASVC, which are applicable in UACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of ASVC, which are applicable in DCUCOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
PSHDW	Shadow price for minimum ancillary service requirement	NRGPRC
ValCurt	Total curtailment of service requirement	NO

Summary for the base-result properties of ASVC, which are applicable in ACOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

ALL
DCUCOPF

Summary for the derived-result properties of ASVC.
Extension	Description	UnitType
Val	Total contribution to service by externals assigned to ancillary service	NO

Summary for the derived-result properties of ASVC, which are applicable in DCUCOPF.
Extension	Description	UnitType
Val	Total contribution to service by externals assigned to ancillary service	NO

ALL
DCUCOPF

Summary for the event-default properties of ASVC.
Extension	Description	UnitType
MinValDef	Default minimum ancillary service requirement value	NO
MinValPriceDef	Default penalty price for not meeting minimum ancillary service requirement	NO

Summary for the event-default properties of ASVC, which are applicable in DCUCOPF.
Extension	Description	UnitType
MinValDef	Default minimum ancillary service requirement value	NO
MinValPriceDef	Default penalty price for not meeting minimum ancillary service requirement	NO

ALL
DCUCOPF

Summary for the event-value properties of ASVC.
Extension	Description	UnitType
MinVal	Minimum ancillary service requirement value	NO
MinValPrice	Penalty price for not meeting minimum ancillary service requirement	NO

Summary for the event-value properties of ASVC, which are applicable in DCUCOPF.
Extension	Description	UnitType
MinVal	Minimum ancillary service requirement value	NO
MinValPrice	Penalty price for not meeting minimum ancillary service requirement	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of ASVC.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
ASVCType	Type of ancillary service
Unit	Unit to be used for ancillary service
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ASVC, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ASVC, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ASVC, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
ASVCType	Type of ancillary service
Unit	Unit to be used for ancillary service
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ASVC, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of ASVC.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ASVC, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ASVC, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ASVC, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ASVC, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
DCUCOPF

Summary for the events of ASVC.
Parameter	Type	Description	UnitType
MinVal	Constraint	Minimum requirement for ancillary service.	NO
MinValPrice	Price	Penalty price for curtailing minimum requirement for ancillary service.	NO
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO

Summary for the events of ASVC, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
MinVal	Constraint	Minimum requirement for ancillary service.	NO
MinValPrice	Price	Penalty price for curtailing minimum requirement for ancillary service.	NO
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO

8.1. Ancillary service external (ASVCX)

Ancillary service externals are defined as external objects that can contribute to a particular ancillary service. The same object can contribute to multiple ancillary services.

Summaries for the properties and events of ASVCX.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of ASVCX.
Extension	Description	UnitType
Val	Contribution to service by the external	NO
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of ASVCX, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of ASVCX, which are applicable in UACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of ASVCX, which are applicable in DCUCOPF.
Extension	Description	UnitType
Val	Contribution to service by the external	NO
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of ASVCX, which are applicable in ACOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

ALL
DCUCOPF

Summary for the event-default properties of ASVCX.
Extension	Description	UnitType
ASVCPriceDef	Default price for contributing to ancillary service	NO
MaxValDef	Default maximum contribution to service by the external	NO

Summary for the event-default properties of ASVCX, which are applicable in DCUCOPF.
Extension	Description	UnitType
ASVCPriceDef	Default price for contributing to ancillary service	NO
MaxValDef	Default maximum contribution to service by the external	NO

ALL
DCUCOPF

Summary for the event-value properties of ASVCX.
Extension	Description	UnitType
ASVCPrice	Price for contributing to ancillary service	NO
MaxVal	Maximum contribution to service by the external	NO

Summary for the event-value properties of ASVCX, which are applicable in DCUCOPF.
Extension	Description	UnitType
ASVCPrice	Price for contributing to ancillary service	NO
MaxVal	Maximum contribution to service by the external	NO

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of ASVCX.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ASVCX, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ASVCX, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ASVCX, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ASVCX, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of ASVCX.
Extension	Description	UnitType
ASVCName	Ancillary service the external is contributing to
NetObjID	External contributing to ancillary service
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ASVCX, which are applicable in ACPF.
Extension	Description	UnitType
ASVCName	Ancillary service the external is contributing to
NetObjID	External contributing to ancillary service
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ASVCX, which are applicable in UACPF.
Extension	Description	UnitType
ASVCName	Ancillary service the external is contributing to
NetObjID	External contributing to ancillary service
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ASVCX, which are applicable in DCUCOPF.
Extension	Description	UnitType
ASVCName	Ancillary service the external is contributing to
NetObjID	External contributing to ancillary service
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ASVCX, which are applicable in ACOPF.
Extension	Description	UnitType
ASVCName	Ancillary service the external is contributing to
NetObjID	External contributing to ancillary service
NetType	Network Type
ID	Object Identification
ObjType	Object Type	NO
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
DCUCOPF

Summary for the events of ASVCX.
Parameter	Type	Description	UnitType
ASVCPrice	Price	Price for providing ancillary service.	NO
MaxVal	Constraint	Maximum contribution to ancillary service.	NO
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO

Summary for the events of ASVCX, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
ASVCPrice	Price	Price for providing ancillary service.	NO
MaxVal	Constraint	Maximum contribution to ancillary service.	NO
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO

9. Electric constraint (ECNSTR)

An object describing customized constraints that a user can create. Such constraints must be "linear constraints". This object is available only in a DCUCOPF scenario.

Summaries for the properties and events of ECNSTR.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of ECNSTR.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
SHDW	Shadow price for constraint	C

Summary for the base-result properties of ECNSTR, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
SHDW	Shadow price for constraint	C

Summary for the base-result properties of ECNSTR, which are applicable in UACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
SHDW	Shadow price for constraint	C

Summary for the base-result properties of ECNSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
SHDW	Shadow price for constraint	C

Summary for the base-result properties of ECNSTR, which are applicable in ACOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state
SHDW	Shadow price for constraint	C

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the derived-result properties of ECNSTR.
Extension	Description	UnitType
SUMLHS	Resulting sum of left hand side of constraint equation	ND

Summary for the derived-result properties of ECNSTR, which are applicable in ACPF.
Extension	Description	UnitType
SUMLHS	Resulting sum of left hand side of constraint equation	ND

Summary for the derived-result properties of ECNSTR, which are applicable in UACPF.
Extension	Description	UnitType
SUMLHS	Resulting sum of left hand side of constraint equation	ND

Summary for the derived-result properties of ECNSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
SUMLHS	Resulting sum of left hand side of constraint equation	ND

Summary for the derived-result properties of ECNSTR, which are applicable in ACOPF.
Extension	Description	UnitType
SUMLHS	Resulting sum of left hand side of constraint equation	ND

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of ECNSTR.
Extension	Description	UnitType
AvgLowBoundDef	Default time averaged lower bound of constraint	ND
AvgUpBoundDef	Default time averaged upper bound of constraint	ND
LowBoundDef	Default lower bound of constraint	ND
UpBoundDef	Default upper bound of constraint	ND

Summary for the event-default properties of ECNSTR, which are applicable in ACPF.
Extension	Description	UnitType
AvgLowBoundDef	Default time averaged lower bound of constraint	ND
AvgUpBoundDef	Default time averaged upper bound of constraint	ND
LowBoundDef	Default lower bound of constraint	ND
UpBoundDef	Default upper bound of constraint	ND

Summary for the event-default properties of ECNSTR, which are applicable in UACPF.
Extension	Description	UnitType
AvgLowBoundDef	Default time averaged lower bound of constraint	ND
AvgUpBoundDef	Default time averaged upper bound of constraint	ND
LowBoundDef	Default lower bound of constraint	ND
UpBoundDef	Default upper bound of constraint	ND

Summary for the event-default properties of ECNSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
AvgLowBoundDef	Default time averaged lower bound of constraint	ND
AvgUpBoundDef	Default time averaged upper bound of constraint	ND
LowBoundDef	Default lower bound of constraint	ND
UpBoundDef	Default upper bound of constraint	ND

Summary for the event-default properties of ECNSTR, which are applicable in ACOPF.
Extension	Description	UnitType
AvgLowBoundDef	Default time averaged lower bound of constraint	ND
AvgUpBoundDef	Default time averaged upper bound of constraint	ND
LowBoundDef	Default lower bound of constraint	ND
UpBoundDef	Default upper bound of constraint	ND

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of ECNSTR.
Extension	Description	UnitType
AvgLowBound	Time averaged lower bound of constraint	ND
AvgUpBound	Time averaged upper bound of constraint	ND
LowBound	Lower bound of constraint	ND
UpBound	Upper bound of constraint	ND

Summary for the event-value properties of ECNSTR, which are applicable in ACPF.
Extension	Description	UnitType
AvgLowBound	Time averaged lower bound of constraint	ND
AvgUpBound	Time averaged upper bound of constraint	ND
LowBound	Lower bound of constraint	ND
UpBound	Upper bound of constraint	ND

Summary for the event-value properties of ECNSTR, which are applicable in UACPF.
Extension	Description	UnitType
AvgLowBound	Time averaged lower bound of constraint	ND
AvgUpBound	Time averaged upper bound of constraint	ND
LowBound	Lower bound of constraint	ND
UpBound	Upper bound of constraint	ND

Summary for the event-value properties of ECNSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
AvgLowBound	Time averaged lower bound of constraint	ND
AvgUpBound	Time averaged upper bound of constraint	ND
LowBound	Lower bound of constraint	ND
UpBound	Upper bound of constraint	ND

Summary for the event-value properties of ECNSTR, which are applicable in ACOPF.
Extension	Description	UnitType
AvgLowBound	Time averaged lower bound of constraint	ND
AvgUpBound	Time averaged upper bound of constraint	ND
LowBound	Lower bound of constraint	ND
UpBound	Upper bound of constraint	ND

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of ECNSTR.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ECNSTR, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ECNSTR, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ECNSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

Summary for the net-input properties of ECNSTR, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of ECNSTR.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ECNSTR, which are applicable in ACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ECNSTR, which are applicable in UACPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ECNSTR, which are applicable in DCUCOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of ECNSTR, which are applicable in ACOPF.
Extension	Description	UnitType
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

ALL
DCUCOPF
ACOPF

Summary for the events of ECNSTR.
Parameter	Type	Description	UnitType
AvgLowBound	Constraint	Time averaged lower bound of constraint.	ND
AvgUpBound	Constraint	Time averaged upper bound of constraint.	ND
LowBound	Constraint	Lower bound of constraint.	ND
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
UpBound	Constraint	Upper bound of constraint.	ND

Summary for the events of ECNSTR, which are applicable in DCUCOPF.
Parameter	Type	Description	UnitType
AvgLowBound	Constraint	Time averaged lower bound of constraint.	ND
AvgUpBound	Constraint	Time averaged upper bound of constraint.	ND
LowBound	Constraint	Lower bound of constraint.	ND
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
UpBound	Constraint	Upper bound of constraint.	ND

Summary for the events of ECNSTR, which are applicable in ACOPF.
Parameter	Type	Description	UnitType
AvgLowBound	Constraint	Time averaged lower bound of constraint.	ND
AvgUpBound	Constraint	Time averaged upper bound of constraint.	ND
LowBound	Constraint	Lower bound of constraint.	ND
OFF	State	Turn off facility, service or object.	NO
ON	State	Turn on facility, service or object.	NO
UpBound	Constraint	Upper bound of constraint.	ND

For each constraint, the bounds are defined by the constraint properties. The bounds are compared to the sum of all variables that are linked to that constraint. Written generally for a constraint with N variables and a scenario with a time horizon containing T timesteps, the bounds are defined as at each timestep t:

ECNSTR.Name.LowBound(t) ≤ ∑_N(EVAR.Name_n.Coeff(t) * EVAR.NetObjID_n.ObjVarName(t))

ECNSTR.Name.UpBound(t) ≥ ∑_N(EVAR.Name_n.Coeff(t) * EVAR.NetObjID_n.ObjVarName(t))

[∑_T(ECNSTR.Name.AvgLowBound(t))] / T ≤ [∑_T∑_N(EVAR.Name.Coeff(t) * EVAR.NetObjID_n.ObjVarName(t))] / T

[∑_T(ECNSTR.Name.AvgUpBound(t))] / T ≥ [∑_T∑_N(EVAR.Name.Coeff(t) * EVAR.NetObjID_n.ObjVarName(t))] / T

As with all default event values, the properties LowBoundDef, UpBoundDef, AvgLowBoundDef, AvgUpBoundDef, and CoeffDef can be overridden in a scenario using events.

9.1. Electric variable (EVAR)

An electric variable object defines the link between an electric variable of an object (e.g., P, etc.) and an electric constraint object.

Summaries for the properties and events of EVAR.

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the base-result properties of EVAR.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of EVAR, which are applicable in ACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of EVAR, which are applicable in UACPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of EVAR, which are applicable in DCUCOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

Summary for the base-result properties of EVAR, which are applicable in ACOPF.
Extension	Description	UnitType
State	Current operating state of object. Permitted states are ON and OFF. When referred to a node, all externals connected to the node inherit the state

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-default properties of EVAR.
Extension	Description	UnitType
CoeffDef	Default coefficient for object variable	ND

Summary for the event-default properties of EVAR, which are applicable in ACPF.
Extension	Description	UnitType
CoeffDef	Default coefficient for object variable	ND

Summary for the event-default properties of EVAR, which are applicable in UACPF.
Extension	Description	UnitType
CoeffDef	Default coefficient for object variable	ND

Summary for the event-default properties of EVAR, which are applicable in DCUCOPF.
Extension	Description	UnitType
CoeffDef	Default coefficient for object variable	ND

Summary for the event-default properties of EVAR, which are applicable in ACOPF.
Extension	Description	UnitType
CoeffDef	Default coefficient for object variable	ND

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the event-value properties of EVAR.
Extension	Description	UnitType
Coeff	Coefficient for object variable	ND

Summary for the event-value properties of EVAR, which are applicable in ACPF.
Extension	Description	UnitType
Coeff	Coefficient for object variable	ND

Summary for the event-value properties of EVAR, which are applicable in UACPF.
Extension	Description	UnitType
Coeff	Coefficient for object variable	ND

Summary for the event-value properties of EVAR, which are applicable in DCUCOPF.
Extension	Description	UnitType
Coeff	Coefficient for object variable	ND

Summary for the event-value properties of EVAR, which are applicable in ACOPF.
Extension	Description	UnitType
Coeff	Coefficient for object variable	ND

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-input properties of EVAR.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
ObjVarName	Name of object variable
Unit	Unit for object variable

Summary for the net-input properties of EVAR, which are applicable in ACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
ObjVarName	Name of object variable
Unit	Unit for object variable

Summary for the net-input properties of EVAR, which are applicable in UACPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
ObjVarName	Name of object variable
Unit	Unit for object variable

Summary for the net-input properties of EVAR, which are applicable in DCUCOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
ObjVarName	Name of object variable
Unit	Unit for object variable

Summary for the net-input properties of EVAR, which are applicable in ACOPF.
Extension	Description	UnitType
Alias	Alternative object name. Any character, including non-alphanumeric, is allowed
Info	Information entered for the object. Any character, including non-alphanumeric, is allowed
InService	Indicates if an object is considered or disregarded in the execution of a scenario. Externals connected to the node inherit the "inService" status of the node
Name	Object Name. Permitted characters are letters, numbers, and underscore ("_"). The name should start with a letter. The name should be unique for each object type.
ObjVarName	Name of object variable
Unit	Unit for object variable

ALL
ACPF
UACPF
DCUCOPF
ACOPF

Summary for the net-read-only properties of EVAR.
Extension	Description	UnitType
CNSTRName	Constraint the variable is referring to
NetObjID	ID of Network Object the variable is referring to
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EVAR, which are applicable in ACPF.
Extension	Description	UnitType
CNSTRName	Constraint the variable is referring to
NetObjID	ID of Network Object the variable is referring to
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EVAR, which are applicable in UACPF.
Extension	Description	UnitType
CNSTRName	Constraint the variable is referring to
NetObjID	ID of Network Object the variable is referring to
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EVAR, which are applicable in DCUCOPF.
Extension	Description	UnitType
CNSTRName	Constraint the variable is referring to
NetObjID	ID of Network Object the variable is referring to
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object

Summary for the net-read-only properties of EVAR, which are applicable in ACOPF.
Extension	Description	UnitType
CNSTRName	Constraint the variable is referring to
NetObjID	ID of Network Object the variable is referring to
NetType	Network Type
ID	Object Identification
ObjType	Object Type
UID	Unique identifier for the object which cannot be changed during the lifetime of the object