PK ! Qmg cimpyorm/Model/Elements/Base.pyfrom typing import Union
from lxml import etree
from lxml.etree import XPath
from sqlalchemy import Column, String, ForeignKey
from cimpyorm.auxiliary import log
from cimpyorm.Model import auxiliary as aux
def prefix_ns(func):
"""
Prefixes a property return value with the elements xml-namespace (if its not the default namespace "cim").
Creates unique labels for properties and classes.
"""
def wrapper(obj):
"""
:param obj: Object that implements the namespace property (E.g. CIMClass/CIMProp)
:return: Representation with substituted namespace
"""
s = func(obj)
res = []
if s and isinstance(s, list):
for element in s:
if element.startswith("#"):
element = "".join(element.split("#")[1:])
for key, value in obj.nsmap.items():
if value in element:
element = element.replace(value, key+"_")
res.append(element)
elif s:
if s.startswith("#"):
s = "".join(s.split("#")[1:])
for key, value in obj.nsmap.items():
if value in s:
s = s.replace(value, key + "_")
res = s
else:
res = None
return res
return wrapper
class SchemaElement(aux.Base):
"""
ABC for schema entities.
"""
__tablename__ = "SchemaElement"
nsmap = None
XPathMap = None
name = Column(String(80), primary_key=True)
label = Column(String(50))
namespace = Column(String(30))
type_ = Column(String(50))
#comment = Column(String(300))
__mapper_args__ = {
"polymorphic_on": type_,
"polymorphic_identity": __tablename__
}
def __init__(self, description=None):
"""
The ABC's constructor
:param description: the (merged) xml node element containing the class's description
"""
if description is None:
log.error(f"Initialisation of CIM model entity without associated "
f"description invalid.")
raise ValueError(f"Initialisation of CIM model entity without "
f"associated description invalid.")
self.description = description
self.Attributes = self._raw_Attributes()
self.name = self._name
self.label = self._label
self.namespace = self._namespace
self.Map = None
@staticmethod
def _raw_Attributes():
return {"name": None, "label": None, "namespace": None}
@classmethod
def _generateXPathMap(cls):
"""
Generator for compiled XPath expressions (those require a namespace map to be present, hence they are compiled
at runtime)
:return: None
"""
cls.XPathMap = {"label": XPath(r"rdfs:label/text()", namespaces=cls.nsmap)}
return cls.XPathMap
@property
@prefix_ns
def _label(self):
"""
Return the class' label
:return: str
"""
return self._raw_property("label")
@property
def _namespace(self) -> Union[str, None]:
if not self.Attributes["namespace"]:
if not any(self.name.startswith(ns+"_") for ns in self.nsmap.keys()):
self.Attributes["namespace"] = "cim"
else:
self.Attributes["namespace"] = self.name.split("_")[0]
return self.Attributes["namespace"]
@property
def _comment(self):
"""
Return the class' label
:return: str
"""
# Fixme: This is very slow and not very nice (each string contains the entire xml header - parsing xpath(
# "*/text()) doesn't work due to the text containing xml tags). Therefore, this is currently disabled
str_ = "".join(str(etree.tostring(content, pretty_print=True)) for content in self.description.xpath(
"rdfs:comment", namespaces=self.nsmap))
return str_
@property
@prefix_ns
def _name(self) -> Union[str, None]:
"""
Accessor for an entities name (with cache)
:return: The entities name as defined in its description
"""
if self.Attributes["name"]:
pass
else:
_n = self.description.values()[0]
self.Attributes["name"] = _n
self.name = self.Attributes["name"]
return self.Attributes["name"]
def _raw_property(self, property_identifier) -> Union[list, str, None]:
"""
Extract a property from the CIM entity
:param property_identifier: property name
:return: The CIM entity's property as a list, a string, or None
"""
if self.Attributes[property_identifier] is None:
xp = self.XPathMap
if property_identifier not in xp.keys():
raise KeyError(f"Invalid property_identifier name {property_identifier}.")
results = xp[property_identifier](self.description) # pylint: disable=unsubscriptable-object
if len(set(results)) == 1:
self.Attributes[property_identifier] = results[0]
elif not results:
self.Attributes[property_identifier] = None
else:
log.warning(f"Ambiguous class property_identifier ({property_identifier}) for {self.name}.")
self.Attributes[property_identifier] = [result for result in set(results)]
return self.Attributes[property_identifier]
def describe(self, fmt="psql"):
print(self)
class CIMPackage(SchemaElement):
__tablename__ = "CIMPackage"
name = Column(String(80), ForeignKey(SchemaElement.name), primary_key=True)
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the package's description
"""
super().__init__(description)
PK ! NqW
, , cimpyorm/Model/Elements/Class.pyfrom collections import OrderedDict, defaultdict
import pandas as pd
from lxml.etree import XPath
from sqlalchemy import Column, String, ForeignKey, Integer
from sqlalchemy.orm import relationship
from tabulate import tabulate
from cimpyorm.auxiliary import log, shorten_namespace
from cimpyorm.Model.Elements import SchemaElement, CIMPackage, CIMEnum, prefix_ns
from cimpyorm.Model.Parseable import Parseable
from cimpyorm.auxiliary import chunks
class CIMClass(SchemaElement):
"""
Class representing a CIM Model Class
"""
__tablename__ = "CIMClass"
name = Column(String(80), ForeignKey(SchemaElement.name), primary_key=True)
package_name = Column(String(50), ForeignKey(CIMPackage.name))
package = relationship(CIMPackage, foreign_keys=package_name, backref="classes")
parent_name = Column(String(50), ForeignKey("CIMClass.name"))
parent = relationship("CIMClass", foreign_keys=parent_name, backref="children", remote_side=[name])
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description=None):
"""
Class constructor
:param description: the (merged) xml node element containing the class's description
"""
super().__init__(description)
self.class_ = None
self.Attributes = self._raw_Attributes()
self.package_name = self._belongsToCategory if not \
isinstance(self._belongsToCategory, list) \
else self._belongsToCategory[0] # pylint: disable=unsubscriptable-object
self.parent_name = self._parent_name
self.props = []
@staticmethod
def _raw_Attributes():
return {**SchemaElement._raw_Attributes(),
**{"parent": None,
"category": None,
"namespace": None}
}
@classmethod
def _generateXPathMap(cls):
"""
Compile XPath Expressions for later use (better performance than tree.xpath(...))
:return: None
"""
super()._generateXPathMap()
Map = {
"parent": XPath(r"rdfs:subClassOf/@rdf:resource", namespaces=cls.nsmap),
"category": XPath(r"cims:belongsToCategory/@rdf:resource", namespaces=cls.nsmap)
}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _belongsToCategory(self):
"""
Return the class' category as determined from the schema
:return: str
"""
return self._raw_property("category")
@property
@prefix_ns
def _parent_name(self):
"""
Return the class' parent as determined from the schema
:return: str
"""
return self._raw_property("parent")
def init_type(self, base):
"""
Initialize ORM type using the CIMClass object
:return: None
"""
log.debug(f"Initializing class {self.name}.")
attrs = OrderedDict()
attrs["__tablename__"] = self.name
self.Map = dict()
if self.parent:
attrs["id"] = Column(String(50), ForeignKey(f"{self.parent.name}.id",
ondelete="CASCADE"), primary_key=True)
log.debug(f"Created id column on {self.name} with FK on {self.parent.name}.")
attrs["__mapper_args__"] = {
"polymorphic_identity": self.name
}
else: # Base class
attrs["type_"] = Column(String(50))
attrs["_source_id"] = Column(Integer, ForeignKey("SourceInfo.id"))
attrs["_source"] = relationship("SourceInfo", foreign_keys=attrs["_source_id"])
attrs["id"] = Column(String(50), primary_key=True)
log.debug(f"Created id column on {self.name} with no inheritance.")
attrs["__mapper_args__"] = {
"polymorphic_on": attrs["type_"],
"polymorphic_identity": self.name}
attrs["_schema_class"] = self
if self.parent:
self.class_ = type(self.name, (self.parent.class_,), attrs)
else: # Base class
self.class_ = type(self.name, (Parseable, base,), attrs)
log.debug(f"Defined class {self.name}.")
def generate(self, nsmap):
for prop in self.props:
prop.generate(nsmap)
def _generate_map(self):
"""
Generate the parse-map so it finds all properties (even those named after the ancestor in the hierarchy)
:return: None
"""
# Make sure the CIM Parent Class is always first in __bases__
if self.parent:
self.Map = {**self.parent._generate_map(), **self.Map} # pylint: disable=no-member
return self.Map
@property
def prop_keys(self):
if self.parent:
return self.parent.prop_keys + [prop.key for prop in self.props]
else:
return [prop.key for prop in self.props]
@property
def all_props(self):
_all_props = {}
for prop in self.props:
if prop.namespace is None or prop.namespace == "cim":
_all_props[prop.label] = prop
else:
_all_props[f"{prop.namespace}_{prop.label}"] = prop
if self.parent:
return {**self.parent.all_props, **_all_props}
else:
return _all_props
def parse_values(self, el, session):
if not self.parent:
argmap = {}
insertables = []
else:
argmap, insertables = self.parent.parse_values(el, session)
props = [prop for prop in self.props if prop.used]
for prop in props:
value = prop.xpath(el)
if prop.many_remote and prop.used:
_id = [el.attrib.values()[0]]
_remote_ids = []
if len(set(value)) > 1:
for raw_value in value:
_remote_ids = _remote_ids + [v for v in raw_value.split("#") if len(v)]
else:
_remote_ids = [v for v in value[0].split("#") if len(v)]
_ids = _id * len(_remote_ids)
# Insert tuples in chunks of 400 elements max
for chunk in chunks(list(zip(_ids, _remote_ids)), 400):
_ins = prop.association_table.insert(
[{f"{prop.domain.label}_id": _id,
f"{prop.range.label}_id": _remote_id}
for (_id, _remote_id) in chunk])
insertables.append(_ins)
elif len(value) == 1 or len(set(value)) == 1:
value = value[0]
if isinstance(prop.range, CIMEnum):
argmap[prop.key] = shorten_namespace(value, self.nsmap)
else:
try:
t = prop.mapped_datatype
if t == "Float":
argmap[prop.key] = float(value)
elif t == "Boolean":
argmap[prop.key] = value.lower() == "true"
elif t == "Integer":
argmap[prop.key] = int(value)
elif len([v for v in value.split("#") if v]) > 1:
log.warning(
f"Ambiguous data values for {self.name}:{prop.key}: {len(set(value))} unique values. "
f"(Skipped)")
# If reference doesn't resolve value is set to None (Validation
# has to catch missing obligatory values)
else:
argmap[prop.key] = value.replace("#", "")
except ValueError:
argmap[prop.key] = value.replace("#", "")
elif len(value) > 1:
log.warning(f"Ambiguous data values for {self.name}:{prop.key}: {len(set(value))} unique values. "
f"(Skipped)")
# If reference doesn't resolve value is set to None (Validation
# has to catch missing obligatory values)
return argmap, insertables
def to_html(self, **kwargs):
df = self.property_table()
return df.to_html(**kwargs)
def describe(self, fmt="psql"):
df = self.property_table()
tab = tabulate(df, headers="keys", showindex=False, tablefmt=fmt, stralign="right")
c = self
inh = dict()
inh["Hierarchy"] = [c.name]
inh["Number of native properties"] = [len(c.props)]
while c.parent:
inh["Hierarchy"].append(c.parent.name)
inh["Number of native properties"].append(len(c.parent.props))
c = c.parent
for val in inh.values():
val.reverse()
inh = tabulate(pd.DataFrame(inh),
headers="keys", showindex=False, tablefmt=fmt, stralign="right")
print(inh + "\n" + tab)
def property_table(self):
table = defaultdict(list)
for key, prop in self.all_props.items():
table["Label"].append(key)
table["Domain"].append(prop.domain.name)
table["Multiplicity"].append(prop.multiplicity)
table["Optional"].append(prop.optional)
try:
table["Datatype"].append(prop.datatype.label)
except AttributeError:
table["Datatype"].append(f"*{prop.range.label}")
try:
nominator_unit = prop.datatype.unit.symbol.label
if nominator_unit.lower() == "none":
nominator_unit = None
except AttributeError:
nominator_unit = None
try:
denominator_unit = prop.datatype.denominator_unit.symbol.label
if denominator_unit.lower() == "none":
denominator_unit = None
except AttributeError:
denominator_unit = None
if nominator_unit and denominator_unit:
table["Unit"].append(f"{nominator_unit}/{denominator_unit}")
elif nominator_unit:
table["Unit"].append(f"{nominator_unit}")
elif denominator_unit:
table["Unit"].append(f"1/{denominator_unit}")
else:
table["Unit"].append("-")
try:
nominator_mpl = prop.datatype.multiplier.value.label
if nominator_mpl.lower() == "none":
nominator_mpl = None
except AttributeError:
nominator_mpl = None
try:
denominator_mpl = prop.datatype.denominator_multiplier.value.label
if denominator_mpl.lower() == "none":
denominator_mpl = None
except AttributeError:
denominator_mpl = None
if nominator_mpl and denominator_mpl:
table["Multiplier"].append(f"{nominator_mpl}/{denominator_mpl}")
elif nominator_mpl:
table["Multiplier"].append(f"{nominator_mpl}")
elif denominator_mpl:
table["Multiplier"].append(f"1/{denominator_mpl}")
else:
table["Multiplier"].append("-")
table["Inferred"].append(not prop.used)
df = pd.DataFrame(table)
return df
PK ! J cimpyorm/Model/Elements/Enum.pyfrom collections import defaultdict
import pandas as pd
from lxml.etree import XPath
from sqlalchemy import Column, String, ForeignKey
from sqlalchemy.orm import relationship
from tabulate import tabulate
from cimpyorm.Model.Elements import SchemaElement, prefix_ns
class CIMEnum(SchemaElement):
__tablename__ = "CIMEnum"
name = Column(String(80), ForeignKey(SchemaElement.name), primary_key=True)
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the enums's description
"""
super().__init__(description)
self.Attributes = self._raw_Attributes()
@staticmethod
def _raw_Attributes():
return {**SchemaElement._raw_Attributes(),
**{"category": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {"category": XPath(r"cims:belongsToCategory/@rdf:resource", namespaces=cls.nsmap)}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _category(self):
"""
Return the enums' category as determined from the schema
:return: str
"""
return self._raw_property("category")
def describe(self, fmt="psql"):
table = defaultdict(list)
for value in self.values:
table["Value"].append(value.label)
df = pd.DataFrame(table)
print(tabulate(df, headers="keys", showindex=False, tablefmt=fmt, stralign="right"))
class CIMEnumValue(SchemaElement):
__tablename__ = "CIMEnumValue"
name = Column(String(80), ForeignKey(SchemaElement.name), primary_key=True)
enum_name = Column(String(50), ForeignKey(CIMEnum.name))
enum = relationship(CIMEnum, foreign_keys=enum_name, backref="values")
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the enums's description
"""
super().__init__(description)
self.Attributes = self._raw_Attributes()
self.enum_name = self._enum_name
@staticmethod
def _raw_Attributes():
return {**SchemaElement._raw_Attributes(),
**{"type": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {"type": XPath(r"rdf:type/@rdf:resource", namespaces=cls.nsmap)}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _enum_name(self):
"""
Return the enums' category as determined from the schema
:return: str
"""
return self._raw_property("type")
PK ! UGV V # cimpyorm/Model/Elements/Property.pyfrom collections import OrderedDict
from typing import Union
from lxml.etree import XPath
from sqlalchemy import Column, String, ForeignKey, Boolean, Float, Integer, Table
from sqlalchemy.orm import relationship, backref
from cimpyorm.auxiliary import log
from cimpyorm.Model import auxiliary as aux
from cimpyorm.Model.Elements import SchemaElement, CIMPackage, CIMClass, CIMEnumValue, CIMEnum, prefix_ns
class CIMDT(SchemaElement):
__tablename__ = "CIMDT"
name = Column(String(80), ForeignKey(SchemaElement.name), primary_key=True)
package_name = Column(String(50), ForeignKey(CIMPackage.name))
package = relationship(CIMPackage, foreign_keys=package_name, backref="datatypes")
stereotype = Column(String(30))
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the enums's description
"""
super().__init__(description)
self.Attributes = self._raw_Attributes()
self.package_name = self._category
self.stereotype = self._stereotype
@staticmethod
def _raw_Attributes():
return {**SchemaElement._raw_Attributes(),
**{"category": None,
"stereotype": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {
"category": XPath(r"cims:belongsToCategory/@rdf:resource", namespaces=cls.nsmap),
"stereotype": XPath(r"cims:stereotype/text()", namespaces=cls.nsmap)
}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _stereotype(self):
"""
Return the enums' category as determined from the schema
:return: str
"""
return self._raw_property("stereotype")
@property
@prefix_ns
def _category(self):
"""
Return the enums' category as determined from the schema
:return: str
"""
return self._raw_property("category")
@property
def mapped_datatype(self):
return self.value.datatype.name
class CIMDTProperty(SchemaElement):
__tablename__ = "CIMDTProperty"
name = Column(String(80), ForeignKey(SchemaElement.name), primary_key=True)
belongs_to_name = Column(String(50), ForeignKey(CIMDT.name))
belongs_to = relationship(CIMDT, foreign_keys=belongs_to_name, backref="props")
multiplicity = Column(String(10))
many_remote = Column(Boolean)
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the property's description
"""
super().__init__(description)
self.associated_class = None
self._inverseProperty = None
self.Attributes = self._raw_Attributes()
self.belongs_to_name = self._domain
self.multiplicity = self._multiplicity
self.many_remote = self._many_remote
@staticmethod
def _raw_Attributes():
return {**SchemaElement._raw_Attributes(),
**{"namespace": None, "domain": None, "multiplicity": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {
"domain": XPath(r"rdfs:domain/@rdf:resource", namespaces=cls.nsmap),
"multiplicity": XPath(r"cims:multiplicity/@rdf:resource", namespaces=cls.nsmap)
}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _domain(self):
"""
Return the class' category as determined from the schema
:return: str
"""
return self._raw_property("domain")
@property
@prefix_ns
def _multiplicity(self):
mp = self._raw_property("multiplicity")
return mp.split("M:")[-1] if not isinstance(mp, list) \
else mp[0].split("M:")[-1] # pylint: disable=unsubscriptable-object
@property
def _many_remote(self):
if isinstance(self._multiplicity, list):
return any([mp[-1] in ["2", "n"] for mp in self._multiplicity]) # pylint: disable=not-an-iterable
else:
return self._multiplicity[-1] in ["2", "n"]
class CIMDTUnit(CIMDTProperty):
__tablename__ = "CIMDTUnit"
name = Column(String(80), ForeignKey(CIMDTProperty.name), primary_key=True)
belongs_to = relationship(CIMDT, foreign_keys=CIMDTProperty.belongs_to_name, backref=backref("unit", uselist=False))
symbol_name = Column(String(50), ForeignKey(CIMEnumValue.name))
symbol = relationship(CIMEnumValue, foreign_keys=symbol_name)
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the enums's description
"""
super().__init__(description)
self.Attributes = self._raw_Attributes()
self.symbol_name = self._symbol
@staticmethod
def _raw_Attributes():
return {**CIMDTProperty._raw_Attributes(),
**{"isFixed": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {"isFixed": XPath(r"cims:isFixed/@rdfs:Literal", namespaces=cls.nsmap)}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _symbol(self):
"""
Return the enums' category as determined from the schema
:return: str
"""
return f"UnitSymbol.{self._raw_property('isFixed')}"
class CIMDTValue(CIMDTProperty):
__tablename__ = "CIMDTValue"
name = Column(String(80), ForeignKey(CIMDTProperty.name), primary_key=True)
belongs_to = relationship(CIMDT, foreign_keys=CIMDTProperty.belongs_to_name,
backref=backref("value", uselist=False))
datatype_name = Column(String(50), ForeignKey(CIMDT.name))
datatype = relationship(CIMDT, foreign_keys=datatype_name, backref="values")
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the property's description
"""
super().__init__(description)
self.Attributes = self._raw_Attributes()
self.datatype_name = self._datatype
@staticmethod
def _raw_Attributes():
return {**CIMDTProperty._raw_Attributes(), **{"datatype": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {"datatype": XPath(r"cims:dataType/@rdf:resource", namespaces=cls.nsmap)}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _datatype(self):
return self._raw_property("datatype")
class CIMDTMultiplier(CIMDTProperty):
__tablename__ = "CIMDTMultiplier"
name = Column(String(80), ForeignKey(CIMDTProperty.name), primary_key=True)
belongs_to = relationship(CIMDT, foreign_keys=CIMDTProperty.belongs_to_name,
backref=backref("multiplier", uselist=False))
value_name = Column(String(50), ForeignKey(CIMEnumValue.name))
value = relationship(CIMEnumValue, foreign_keys=value_name)
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the enums's description
"""
super().__init__(description)
self.Attributes = self._raw_Attributes()
self.value_name = self._value
@staticmethod
def _raw_Attributes():
return {**CIMDTProperty._raw_Attributes(),
**{"isFixed": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {"isFixed": XPath(r"cims:isFixed/@rdfs:Literal", namespaces=cls.nsmap)}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _value(self):
"""
Return the enums' category as determined from the schema
:return: str
"""
return f"UnitMultiplier.{self._raw_property('isFixed')}"
class CIMDTDenominatorUnit(CIMDTProperty):
__tablename__ = "CIMDTDenominatorUnit"
name = Column(String(80), ForeignKey(CIMDTProperty.name), primary_key=True)
belongs_to = relationship(CIMDT, foreign_keys=CIMDTProperty.belongs_to_name,
backref=backref("denominator_unit", uselist=False))
symbol_name = Column(String(50), ForeignKey(CIMEnumValue.name))
symbol = relationship(CIMEnumValue, foreign_keys=symbol_name)
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the enums's description
"""
super().__init__(description)
self.Attributes = self._raw_Attributes()
self.symbol_name = self._symbol
@staticmethod
def _raw_Attributes():
return {**CIMDTProperty._raw_Attributes(),
**{"isFixed": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {"isFixed": XPath(r"cims:isFixed/@rdfs:Literal", namespaces=cls.nsmap)}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _symbol(self):
"""
Return the enums' category as determined from the schema
:return: str
"""
return f"UnitSymbol.{self._raw_property('isFixed')}"
class CIMDTDenominatorMultiplier(CIMDTProperty):
__tablename__ = "CIMDTDenominatorMultiplier"
name = Column(String(80), ForeignKey(CIMDTProperty.name), primary_key=True)
belongs_to = relationship(CIMDT, foreign_keys=CIMDTProperty.belongs_to_name,
backref=backref("denominator_multiplier", uselist=False))
value_name = Column(String(50), ForeignKey(CIMEnumValue.name))
value = relationship(CIMEnumValue, foreign_keys=value_name)
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the enums's description
"""
super().__init__(description)
self.Attributes = self._raw_Attributes()
self.value_name = self._value
@staticmethod
def _raw_Attributes():
return {**CIMDTProperty._raw_Attributes(),
**{"isFixed": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {"isFixed": XPath(r"cims:isFixed/@rdfs:Literal", namespaces=cls.nsmap)}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
@prefix_ns
def _value(self):
"""
Return the enums' category as determined from the schema
:return: str
"""
return f"UnitMultiplier.{self._raw_property('isFixed')}"
class CIMProp(SchemaElement):
"""
Class representing a CIM Model property
"""
# pylint: disable=too-many-instance-attributes
__tablename__ = "CIMProp"
XPathMap = None
name = Column(String(80), ForeignKey(SchemaElement.name), primary_key=True)
prop_name = Column(String(50))
cls_name = Column(String(50), ForeignKey(CIMClass.name))
cls = relationship(CIMClass, foreign_keys=cls_name, backref="props")
datatype_name = Column(String(50), ForeignKey(CIMDT.name))
datatype = relationship(CIMDT, foreign_keys=datatype_name, backref="usedby")
inverse_property_name = Column(String(80), ForeignKey("CIMProp.name"))
inverse = relationship("CIMProp", foreign_keys=inverse_property_name, uselist=False)
domain_name = Column(String(50), ForeignKey(CIMClass.name))
domain = relationship(CIMClass, foreign_keys=domain_name, backref="domain_elements")
range_name = Column(String(50), ForeignKey(CIMClass.name))
range = relationship(CIMClass, foreign_keys=range_name, backref="range_elements")
used = Column(Boolean)
multiplicity = Column(String(10))
many_remote = Column(Boolean)
optional = Column(Boolean)
__mapper_args__ = {
"polymorphic_identity": __tablename__
}
def __init__(self, description):
"""
Class constructor
:param description: the (merged) xml node element containing the property's description
"""
super().__init__(description)
self._inverseProperty = None
self.Attributes = self._raw_Attributes()
self.cls_name = self._domain
self.prop_name = self.name.split(".")[-1]
self.datatype_name = self._datatype
self.inverse_property_name = self._inversePropertyName
self.domain_name = self._domain
self.range_name = self._range
self.used = self._used
self.multiplicity = self._multiplicity
self.many_remote = self._many_remote
self.optional = self._optional
self.key = None
self.var_key = None
self.xpath = None
self.association_table = None
@staticmethod
def _raw_Attributes():
return {**SchemaElement._raw_Attributes(),
**{"range": None, "used": None, "association": None, "domain": None, "inverseRoleName": None,
"multiplicity": None, "datatype": None, "namespace": None}}
@classmethod
def _generateXPathMap(cls):
super()._generateXPathMap()
Map = {
"label": XPath(r"rdfs:label/text()", namespaces=cls.nsmap),
"association": XPath(r"cims:AssociationUsed/text()", namespaces=cls.nsmap),
"inverseRoleName": XPath(r"cims:inverseRoleName/@rdf:resource", namespaces=cls.nsmap),
"datatype": XPath(r"cims:dataType/@rdf:resource", namespaces=cls.nsmap),
"multiplicity": XPath(r"cims:multiplicity/@rdf:resource", namespaces=cls.nsmap),
"type": XPath(r"rdf:type/@rdf:resource", namespaces=cls.nsmap),
"domain": XPath(r"rdfs:domain/@rdf:resource", namespaces=cls.nsmap),
"range": XPath(r"rdfs:range/@rdf:resource", namespaces=cls.nsmap)
}
if not cls.XPathMap:
cls.XPathMap = Map
else:
cls.XPathMap = {**cls.XPathMap, **Map}
@property
def _used(self):
"""
Determine whether the property needs to be added to the SQLAlchemy declarative class (i.e. it is not an
inverseProperty of an existing mapper or it maps to a value, not a reference).
:return: True if property should be represented in the SQLAlchemy declarative model.
"""
return bool(self._association) or self._inversePropertyName is None
@property
@prefix_ns
def _datatype(self):
return self._raw_property("datatype")
@property
@prefix_ns
def _multiplicity(self):
mp = self._raw_property("multiplicity")
return mp.split("M:")[-1] if not isinstance(mp, list) \
else mp[0].split("M:")[-1] # pylint: disable=unsubscriptable-object
@property
def _association(self) -> Union[bool, None]:
association = self._raw_property("association")
if not association:
return None
elif isinstance(association, list):
if len(set(association)) == 1:
return association[0] == "Yes" # pylint: disable=E1136
elif not set(association):
return None
else:
raise ValueError(f"Ambiguous association used parameter for property {self.name}.")
else:
return association == "Yes"
@property
@prefix_ns
def _inversePropertyName(self):
return self._raw_property("inverseRoleName")
@property
@prefix_ns
def _range(self):
return self._raw_property("range")
@property
@prefix_ns
def _domain(self):
return self._raw_property("domain")
@property
def mapped_datatype(self): # pylint: disable=inconsistent-return-statements
if self.datatype:
if self.datatype.stereotype == "Primitive":
return self.datatype.name
elif self.datatype.stereotype == "CIMDatatype":
return self.datatype.mapped_datatype
else:
return None
@property
def _many_remote(self):
if isinstance(self._multiplicity, list):
return any([mp[-1] in ["2", "n"] for mp in self._multiplicity]) # pylint: disable=not-an-iterable
else:
return self._multiplicity[-1] in ["2", "n"]
@property
def _optional(self):
if isinstance(self._multiplicity, list):
return any([mp.startswith("0") for mp in self._multiplicity]) # pylint: disable=not-an-iterable
else:
return self._multiplicity.startswith("0")
def generate(self, nsmap):
attrs = OrderedDict()
dt = self.mapped_datatype
if self.used:
if isinstance(self.range, CIMEnum):
var, query_base = self.name_query()
attrs[f"{var}_name"] = Column(String(120), ForeignKey(CIMEnumValue.name), name=f"{var}_name")
attrs[var] = relationship(CIMEnumValue,
foreign_keys=attrs[f"{var}_name"])
self.key = f"{var}_name"
self.xpath = XPath(query_base + "/@rdf:resource", namespaces=nsmap)
elif self.range:
self.generate_relationship(nsmap)
elif not self.range:
var, query_base = self.name_query()
log.debug(f"Generating property for {var} on {self.name}")
self.key = var
self.xpath = XPath(query_base + "/text()", namespaces=nsmap)
if dt:
if dt == "String":
attrs[var] = Column(String(50), name=f"{var}")
elif dt in ("Float", "Decimal"):
attrs[var] = Column(Float, name=f"{var}")
elif dt == "Integer":
attrs[var] = Column(Integer, name=f"{var}")
elif dt == "Boolean":
attrs[var] = Column(Boolean, name=f"{var}")
else:
attrs[var] = Column(String(30), name=f"{var}")
else:
# Fallback to parsing as String(50)
attrs[var] = Column(String(50), name=f"{var}")
for attr, attr_value in attrs.items():
setattr(self.cls.class_, attr, attr_value)
def set_var_key(self):
end = ""
if isinstance(self.range, CIMEnum):
end = "_name"
elif self.range:
end = "_id"
self.var_key = self.namespace + "_" + self.label if self.namespace != "cim" else self.label + end
def name_query(self):
var = self.namespace + "_" + self.label if self.namespace != "cim" else self.label
query_base = f"{self.domain.label}.{self.label}" if self.domain.label.startswith(self.namespace) else \
f"{self.namespace}:{self.domain.label}.{self.label}"
return var, query_base
def generate_relationship(self, nsmap=None):
var, query_base = self.name_query()
attrs = {}
Map = {}
log.debug(f"Generating relationship for {var} on {self.name}")
if self.many_remote:
if self.inverse:
br = self.inverse.label if self.namespace == "cim" else self.namespace + "_" + self.inverse.label
tbl = self.generate_association_table()
self.association_table = tbl
attrs[var] = relationship(self.range.label,
secondary=tbl,
backref=br)
else:
tbl = self.generate_association_table()
attrs[var] = relationship(self.range.label,
secondary=tbl)
else:
attrs[f"{var}_id"] = Column(String(50),
ForeignKey(f"{self.range.label}.id"),
name=f"{var}_id")
if self.inverse:
br = self.inverse.label if self.namespace == "cim" else self.namespace+"_"+self.inverse.label
attrs[var] = relationship(self.range.label,
foreign_keys=attrs[f"{var}_id"],
backref=br)
else:
attrs[var] = relationship(self.range.label,
foreign_keys=attrs[f"{var}_id"])
self.key = f"{var}_id"
self.xpath = XPath(query_base + "/@rdf:resource", namespaces=nsmap)
class_ = self.cls.class_
for attr, attr_value in attrs.items():
setattr(class_, attr, attr_value)
return Map
def generate_association_table(self):
association_table = Table(f".asn_{self.domain.label}_{self.range.label}", aux.Base.metadata,
Column(f"{self.range.label}_id", String(50), ForeignKey(f"{self.range.label}.id")),
Column(f"{self.domain.label}_id", String(50), ForeignKey(f"{self.domain.label}.id")))
return association_table
PK ! yfU U # cimpyorm/Model/Elements/__init__.pyfrom .Base import *
from .Enum import *
from .Class import *
from .Property import *
PK ! ; ; cimpyorm/Model/Parseable.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
from lxml.etree import XPath
class Parseable:
"""
Base class for CIM classes that are to be parsed from CIM instance, providing
parse methods for static (rdf:ID) objects and supplementary (rdf:about)
information.
"""
Map = {}
_about_ref = None
ObjectName = None
_schema_class = None
@classmethod
def compile_map(cls, nsmap):
"""
Compile the XPath map for the parsing run
:param nsmap: The .xml nsmap
:return: None
"""
attribute_map = cls.Map
for key, element in cls.Map.items():
if key not in cls.__bases__[0].Map: # pylint: disable=no-member
attribute_map[key] = XPath(element, namespaces=nsmap)
cls.Map = attribute_map
@classmethod
def fields(cls):
"""
Print information about available fields in Class
:return: None
"""
print(f"Fields available for class {cls.__name__}")
[print(var) for var in vars(cls).keys() if not var.startswith("_")] # pylint: disable=expression-not-assigned
@classmethod
def describe(cls, fmt="psql"):
cls._schema_class.describe(fmt)
@classmethod
def to_html(cls, **kwargs):
return cls._schema_class.to_html(**kwargs)
PK ! e- - cimpyorm/Model/Schema.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
import json
from argparse import Namespace
from collections import defaultdict
import lxml.etree as et
from lxml.etree import XPath
import networkx as nx
from networkx import DiGraph, bfs_tree
from networkx.exception import NetworkXNoPath
from sqlalchemy import Column, TEXT, Integer
from sqlalchemy.exc import InvalidRequestError
from cimpyorm.auxiliary import log, merge, HDict, merge_descriptions, find_rdfs_path
import cimpyorm.Model.auxiliary as aux
from cimpyorm.Model.Elements import CIMPackage, CIMClass, CIMProp, CIMDT, CIMEnum, CIMEnumValue, \
CIMDTUnit, CIMDTValue, CIMDTMultiplier, CIMDTDenominatorUnit, SchemaElement, CIMDTProperty, \
CIMDTDenominatorMultiplier
from cimpyorm.backends import InMemory
class Schema:
def __init__(self, session=None, version: str = "16"):
"""
Initialize a Backend object, containing information about the schema elements
:param file_or_tree: The schema file or a parsed root
"""
self.g = None
if not session:
backend = InMemory()
backend.reset()
session = backend.session
rdfs_path = find_rdfs_path(version)
if not rdfs_path:
raise FileNotFoundError("Failed to find schema file. Please provide one.")
tree = merge(rdfs_path)
log.info(f"Dynamic code generation.")
if session.query(SchemaElement).count():
# A schema is already present, so just load it instead of recreating
self.session = session
self.Element_classes = {c.__name__: c for c in
[CIMPackage, CIMClass, CIMProp, CIMDT, CIMEnum, CIMEnumValue, CIMDTUnit,
CIMDTValue, CIMDTMultiplier, CIMDTDenominatorUnit, CIMDTDenominatorMultiplier]}
self.Elements = {c.__name__: {cim_class.name: cim_class for cim_class in session.query(c).all()}
for c in self.Element_classes.values()}
else:
self.session = session
if isinstance(tree, type(et.ElementTree())):
self.file = None
self.root = tree.getroot()
else:
self.file = tree
self.root = et.parse(tree).getroot()
self.Element_classes = {c.__name__: c for c in
[CIMPackage, CIMClass, CIMProp, CIMDT, CIMEnum, CIMEnumValue, CIMDTUnit,
CIMDTValue, CIMDTMultiplier, CIMDTDenominatorUnit, CIMDTDenominatorMultiplier]}
self.Elements = {c.__name__: defaultdict(list) for c in self.Element_classes.values()}
self._init_parser()
self._generate()
for _, Cat_Elements in self.Elements.items():
self.session.add_all(list(Cat_Elements.values()))
self.session.commit()
log.debug(f"Backend generated")
session.add(SchemaInfo(self.root.nsmap))
self.init_model(session)
@property
def inheritance_graph(self):
"""
Determine the class inheritance hierarchy (class definition needs to adhere to strict inheritance hierarchy)
:param classes: dict of CIMClass objects
:return: g - A networkx DiGraph of the class hierarchy, with a common ancestor __root__
"""
# Determine class inheritance hierarchy (bfs on a directed graph)
g = DiGraph()
g.add_node("__root__")
class_list = list(self.session.query(CIMClass).all())
while class_list:
for element in class_list:
if element:
parent = element.parent
if not parent:
g.add_edge("__root__", element)
else:
g.add_edge(parent, element)
class_list.remove(element)
return g
def _init_parser(self):
SchemaElement.nsmap = HDict(self.root.nsmap)
for c in self.Element_classes.values():
c._generateXPathMap()
@staticmethod
def _isclass(type_res):
return type_res and type_res[0].endswith("#Class")
@staticmethod
def _isenum(stype_res):
return stype_res and stype_res[0].endswith("#enumeration")
@staticmethod
def _isdt(stype_txt):
return stype_txt and stype_txt[0] in ["CIMDatatype", "Primitive"]
@staticmethod
def _isprop(type_res):
return type_res and type_res[0].endswith("#Property")
@staticmethod
def _ispackage(type_res):
return type_res and type_res[0].endswith("#ClassCategory")
@property
def model(self):
for class_ in self.session.query(CIMClass).all():
class_.p = Namespace(**class_.all_props)
for enum_ in self.session.query(CIMEnum).all():
enum_.v = Namespace(**{value.label: value for value in enum_.values})
return Namespace(**{c.name: c.class_ for c in self.session.query(CIMClass).all()},
**{"dt": Namespace(**{c.name: c for c in self.session.query(CIMDT).all()})},
**{"classes": Namespace(**{c.name: c for c in self.session.query(CIMClass).all()})},
**{"enum": Namespace(**{c.name: c for c in self.session.query(CIMEnum).all()})})
def _generate(self):
xp_type_res = XPath(f"rdf:type/@rdf:resource", namespaces=self.root.nsmap)
xp_stype_res = XPath(f"cims:stereotype/@rdf:resource", namespaces=self.root.nsmap)
xp_stype_txt = XPath(f"cims:stereotype/text()", namespaces=self.root.nsmap)
postponed = []
for element in self.root:
type_res = xp_type_res(element)
stype_res = xp_stype_res(element)
stype_txt = xp_stype_txt(element)
if Schema._isclass(type_res):
if Schema._isenum(stype_res):
obj = CIMEnum(element)
self.Elements["CIMEnum"][obj.name].append(obj)
elif Schema._isdt(stype_txt):
obj = CIMDT(element)
self.Elements["CIMDT"][obj.name].append(obj)
else:
obj = CIMClass(element)
self.Elements["CIMClass"][obj.name].append(obj)
elif Schema._isprop(type_res):
postponed.append(element)
elif Schema._ispackage(type_res):
obj = CIMPackage(element)
self.Elements["CIMPackage"][obj.name].append(obj)
elif type_res:
postponed.append(element)
else:
obj = SchemaElement(element)
log.warning(f"Element skipped: {obj.name}")
for element in postponed:
type_res = xp_type_res(element)
if Schema._isprop(type_res):
obj = CIMProp(element)
if obj._domain in self.Elements["CIMDT"].keys():
if obj.name.endswith(".unit"):
obj = CIMDTUnit(element)
self.Elements["CIMDTUnit"][obj.name].append(obj)
elif obj.name.endswith(".value"):
obj = CIMDTValue(element)
self.Elements["CIMDTValue"][obj.name].append(obj)
elif obj.name.endswith(".multiplier"):
obj = CIMDTMultiplier(element)
self.Elements["CIMDTMultiplier"][obj.name].append(obj)
elif obj.name.endswith(".denominatorUnit"):
obj = CIMDTDenominatorUnit(element)
self.Elements["CIMDTDenominatorUnit"][obj.name].append(obj)
elif obj.name.endswith(".denominatorMultiplier"):
obj = CIMDTDenominatorMultiplier(element)
self.Elements["CIMDTDenominatorMultiplier"][obj.name].append(obj)
else:
obj = CIMDTProperty(element)
self.Elements["CIMDTProperty"][obj.name].append(obj)
else:
self.Elements["CIMProp"][obj.name].append(obj)
continue
obj = CIMEnumValue(element)
if obj._enum_name and obj._enum_name in self.Elements["CIMEnum"].keys():
self.Elements["CIMEnumValue"][obj.name].append(obj)
else:
log.debug(f"Failed to identify purpose for {type_res}")
self._merge_elements()
for key, value in self.Elements.items():
if value:
log.debug(f"Generated {len(value)} {key}.")
@property
def map(self):
if not self.g:
g = DiGraph()
classes = self.session.query(CIMClass).all()
enums = self.session.query(CIMEnum).all()
g.add_nodes_from(classes)
g.add_nodes_from(enums)
g.add_nodes_from(self.session.query(CIMProp).all())
for node in classes + enums:
try:
for prop in node.all_props.values():
if prop.range:
g.add_edge(node, prop.range, label=prop.label)
else:
g.add_edge(node, prop, label=prop.label)
except AttributeError:
pass
self.g = g
return self.g
def path(self, source, destination):
if source == destination:
return
try:
path = nx.shortest_path(self.map, source, destination)
except NetworkXNoPath:
log.error(f"No path between {source.name} and {destination.name}.")
return
way = []
for iter in range(1, len(path)):
way.append(self.map.edges[path[iter-1], path[iter]]["label"])
return way
def _merge_elements(self):
for Category, CatElements in self.Elements.items():
log.debug(f"Merging {Category}.")
for NodeName, NodeElements in CatElements.items():
CatElements[NodeName] = self.Element_classes[Category](
merge_descriptions([e.description for e in NodeElements]))
self.Elements[Category] = dict(CatElements)
def init_model(self, session):
g = self.inheritance_graph
additionalNodes = list(bfs_tree(g, "__root__"))
additionalNodes.remove("__root__")
hierarchy = additionalNodes
try:
for c in hierarchy:
c.init_type(aux.Base)
except InvalidRequestError:
pass
session.commit()
session.flush()
nsmap = session.query(SchemaInfo).one().nsmap
for c in hierarchy:
c.generate(nsmap)
log.info(f"Generated {len(hierarchy)} classes")
class SchemaInfo(aux.Base):
__tablename__ = "SchemaInfo"
namespaces = Column(TEXT)
id = Column(Integer, primary_key=True, autoincrement=True)
def __init__(self, nsmap):
"""
Initialize SchemaInfo object
:param source_file: Path to the file containing the model data
"""
self.namespaces = json.dumps(nsmap)
@property
def nsmap(self):
"""
Return the source's nsmap
:return: dict - The source's nsmap
"""
nsmap = json.loads(self.namespaces)
return nsmap
PK !
cimpyorm/Model/Source.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
import json
import re
from collections import defaultdict
from pathlib import Path
from typing import Union
from functools import lru_cache
import lxml.etree as et
from sqlalchemy import Column, Integer, String, TEXT
from cimpyorm.auxiliary import HDict
import cimpyorm.Model.auxiliary as aux
class SourceInfo(aux.Base):
"""
Class for storing source metadata in the database
"""
__tablename__ = "SourceInfo"
id = Column(Integer, primary_key=True, autoincrement=True)
filename = Column(String(50))
uuid = Column(String(50))
FullModel = Column(TEXT)
namespaces = Column(TEXT)
def __init__(self, source_file):
"""
Initialize DataSource object
:param source_file: Path to the file containing the model data
"""
self.source = source_file
self._parse_meta()
def __repr__(self):
"""
Unique representation
:return: str
"""
fm = json.loads(self.FullModel)
str_ = f"source uuid: {self.uuid} | filename: {self.filename} | profiles: {fm['profile']}"
return str_
@property
def cim_version(self):
"""
Return the source's cim_version
:return: str - The source's cim version
"""
nsmap = HDict(json.loads(self.namespaces))
return _get_cimrdf_version(nsmap["cim"])
@property
@lru_cache()
def nsmap(self):
"""
Return the source's nsmap
:return: dict - The source's nsmap
"""
nsmap = HDict(json.loads(self.namespaces))
return nsmap
def _parse_meta(self):
try:
self.filename = Path(self.source).name
except TypeError:
self.filename = self.source.name
self.tree = et.parse(self.source)
root = self.tree.getroot()
nsmap = root.nsmap
uuid, metadata = self._generate_metadata()
self.uuid = uuid
self.FullModel = json.dumps(metadata)
self.namespaces = json.dumps(nsmap)
def _generate_metadata(self):
"""
Determine the data source's metadata (such as CIM version)
:return: (data source uuid, data source metadata)
"""
tree = self.tree
nsmap = tree.getroot().nsmap
source = tree.xpath("md:FullModel", namespaces=nsmap)[0]
uuid = source.xpath("@rdf:about", namespaces=nsmap)[0].split("urn:uuid:")[-1]
metadata = defaultdict(list)
for element in source:
entry = element.tag.split("Model.")[-1]
value = element.text if entry != "DependentOn" else element.attrib.values()[0].split("urn:uuid:")[-1]
if value not in metadata[entry]:
metadata[entry].append(value)
return uuid, metadata
def _get_cimrdf_version(cim_ns) -> Union[None, str]:
"""
Parse the cim namespace into a version number
:param cim_ns: cim namespace
:return: double, version number, or None if no version could be identified
"""
match = re.search(r"(?<=CIM-schema-cim)\d{0,2}?(?=#)", cim_ns)
if match:
return match.group()
else:
return None
PK ! wE= = cimpyorm/Model/__init__.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
PK ! cimpyorm/Model/auxiliary.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
from sqlalchemy.ext.declarative import declarative_base
Base = declarative_base()
PK ! &
cimpyorm/Parser.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
from sys import stdout
from itertools import chain
from collections import defaultdict
from functools import lru_cache
from tqdm import tqdm
from cimpyorm.auxiliary import HDict, log, parseable_files, shorten_namespace
def get_files(dataset):
if isinstance(dataset, list):
files = chain(*[parseable_files(path) for path in dataset])
else:
files = parseable_files(dataset)
return files
def merge_sources(sources):
d_ = defaultdict(dict)
from lxml.etree import XPath
xp = {"id": XPath("@rdf:ID", namespaces=get_nsmap(sources)),
"about": XPath("@rdf:about", namespaces=get_nsmap(sources))}
for source in sources:
for element in source.tree.getroot():
try:
uuid = determine_uuid(element, xp)
classname = shorten_namespace(element.tag, HDict(get_nsmap(sources)))
if classname not in d_ or uuid not in d_[classname].keys():
d_[classname][uuid] = element
else:
[d_[classname][uuid].append(sub) for sub in element] # pylint: disable=expression-not-assigned
except ValueError:
log.warning(f"Skipped element during merge: {element}.")
return d_
def parse_entries(entries, schema):
classes = dict(schema.session.query(
schema.Element_classes["CIMClass"].name,
schema.Element_classes["CIMClass"]
).all())
created = []
for classname, elements in entries.items():
if classname in classes.keys():
for uuid, element in tqdm(elements.items(), desc=f"Reading {classname}", leave=False):
argmap, insertables = classes[classname].parse_values(element, schema.session)
created.append(classes[classname].class_(id="_"+uuid,
**argmap))
for insertable in insertables:
schema.session.execute(insertable)
else:
log.info(f"{classname} not implemented. Skipping.")
return created
def determine_uuid(element, xp):
uuid = None
try:
_id = xp["id"](element)[0]
if _id.startswith("_"):
_id = _id[1:]
uuid = _id
except IndexError:
pass
try:
about = xp["about"](element)[0].split("urn:uuid:")[-1].split("#_")[-1]
uuid = about
except IndexError:
pass
return uuid
@lru_cache()
def get_nsmap(sources: frozenset):
"""
Return the merged namespace map for a list of data sources
:param sources: frozenset of DataSource objects (so its hashable)
:return: dict, merged nsmap of all DataSource objects
"""
nsmaps = [source.nsmap for source in sources]
nsmaps = {k: v for d in nsmaps for k, v in d.items()}
return HDict(nsmaps)
def get_cim_version(sources):
"""
Return the (unambiguous) DataSource cim versions
:param sources: DataSources
:return:
"""
cim_versions = [source.cim_version for source in sources]
if len(set(cim_versions)) > 1:
log.error(f"Ambiguous cim_versions: {cim_versions}.")
return cim_versions[0]
PK ! - cimpyorm/Test/Integration/MariaDB/__init__.pyPK ! >
; cimpyorm/Test/Integration/MariaDB/test_integration_tests.pyimport cimpyorm.auxiliary
from cimpyorm.api import load, parse
import pytest
import cimpyorm
from cimpyorm.backends import MariaDB
def test_parse_load(full_grid):
try:
cimpyorm.auxiliary.get_path("SCHEMAROOT")
except KeyError:
pytest.skip(f"Schemata not configured")
path = "integration_test"
session, m = parse(full_grid, MariaDB(path=path, host="localhost"))
session.close()
session, m = load(MariaDB(path=path, host="localhost"))
session.close()
MariaDB(path=path, host="localhost").drop()
def test_parse_parse(full_grid):
try:
cimpyorm.auxiliary.get_path("SCHEMAROOT")
except KeyError:
pytest.skip(f"Schemata not configured")
path = "integration_test"
session, m = parse(full_grid, MariaDB(path=path, host="localhost"))
session.close()
session, m = parse(full_grid, MariaDB(path=path, host="localhost"))
assert session.query(m.Terminal).first().ConductingEquipment
session.close()
MariaDB(path=path, host="localhost").drop()
PK ! + cimpyorm/Test/Integration/MySQL/__init__.pyPK ! y 9 cimpyorm/Test/Integration/MySQL/test_integration_tests.pyimport cimpyorm.auxiliary
from cimpyorm.api import load, parse
import pytest
import cimpyorm
from cimpyorm.backends import MySQL
def test_parse_load(full_grid):
try:
cimpyorm.auxiliary.get_path("SCHEMAROOT")
except KeyError:
pytest.skip(f"Schemata not configured")
path = "integration_test"
session, m = parse(full_grid, MySQL(path=path, host="localhost"))
session.close()
session, m = load(MySQL(path=path, host="localhost"))
session.close()
MySQL(path=path, host="localhost").drop()
def test_parse_parse(full_grid):
try:
cimpyorm.auxiliary.get_path("SCHEMAROOT")
except KeyError:
pytest.skip(f"Schemata not configured")
path = "integration_test"
session, m = parse(full_grid, MySQL(path=path, host="localhost"))
session.close()
session, m = parse(full_grid, MySQL(path=path, host="localhost"))
assert session.query(m.Terminal).first().ConductingEquipment
session.close()
MySQL(path=path, host="localhost").drop()
PK ! , cimpyorm/Test/Integration/SQLite/__init__.pyPK ! " : cimpyorm/Test/Integration/SQLite/test_integration_tests.pyimport cimpyorm.auxiliary
from cimpyorm.api import load, parse
import os
import pytest
import cimpyorm
from cimpyorm.backends import SQLite, InMemory
def test_parse_inmemory(full_grid):
try:
cimpyorm.auxiliary.get_path("SCHEMAROOT")
except KeyError:
pytest.skip(f"Schemata not configured")
session, m = parse(full_grid, InMemory())
session.close()
def test_parse_load(full_grid):
try:
cimpyorm.auxiliary.get_path("SCHEMAROOT")
except KeyError:
pytest.skip(f"Schemata not configured")
path = os.path.join(full_grid, ".integration_test.db")
session, m = parse(full_grid, SQLite(path=path))
session.close()
session, m = load(path)
session.close()
os.remove(path)
def test_parse_parse(full_grid):
try:
cimpyorm.auxiliary.get_path("SCHEMAROOT")
except KeyError:
pytest.skip(f"Schemata not configured")
path = os.path.join(full_grid, ".integration_test.db")
session, m = parse(full_grid, SQLite(path=path))
session.close()
session, m = parse(full_grid, SQLite(path=path))
assert session.query(m.Terminal).first().ConductingEquipment
session.close()
os.remove(path)
PK ! % cimpyorm/Test/Integration/__init__.pyPK ! > > cimpyorm/Test/__init__.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
PK ! (yaGU U cimpyorm/Test/conftest.pyimport pytest
import os
# Keep import for _CONFIGPATH - otherwise get_path fails because cimpyorm/__init__.py locals aren't present
from cimpyorm.auxiliary import log, get_path
@pytest.fixture(scope="session")
def full_grid():
try:
path = os.path.join(get_path("DATASETROOT"), "FullGrid")
except KeyError:
pytest.skip(f"Dataset path not configured")
if not os.path.isdir(path) or not os.listdir(path):
pytest.skip("Dataset 'FullGrid' not present.")
else:
return path
@pytest.fixture(scope="module")
def acquire_db():
import cimpyorm.backends
backend = cimpyorm.backends.SQLite()
engine = backend.engine
session = backend.session
return engine, session
@pytest.fixture(scope="session")
def load_test_db():
"""
Returns a session and a model for a database that's only supposed to be read from
:return: session, m
"""
from cimpyorm.api import load
path = os.path.join(get_path("DATASETROOT"), "FullGrid", "StaticTest.db")
if not os.path.isfile(path):
pytest.skip("StaticTest.db not present.")
session, m = load(path)
return session, m
@pytest.fixture(scope="session")
def dummy_source():
try:
path = os.path.join(get_path("DATASETROOT"), "FullGrid", "20171002T0930Z_BE_EQ_4.xml")
except KeyError:
pytest.skip(f"Dataset path not configured")
if not os.path.isfile(path):
pytest.skip("Dataset 'FullGrid' not present.")
from cimpyorm.Model.Source import SourceInfo
ds = SourceInfo(source_file=path)
return ds
@pytest.fixture(scope="session")
def dummy_nsmap():
from cimpyorm.auxiliary import HDict
nsmap = HDict({'cim': 'http://iec.ch/TC57/2013/CIM-schema-cim16#',
'entsoe': 'http://entsoe.eu/CIM/SchemaExtension/3/1#',
'md': 'http://iec.ch/TC57/61970-552/ModelDescription/1#',
'rdf': 'http://www.w3.org/1999/02/22-rdf-syntax-ns#'})
return nsmap
@pytest.fixture(scope="session")
def cgmes_schema():
from cimpyorm.Model.Schema import Schema
schema = Schema(version="16")
return schema
PK ! $ " cimpyorm/Test/test_aux_and_misc.pyfrom cimpyorm.auxiliary import shorten_namespace
def test_get_class_names_cim(dummy_nsmap):
assert shorten_namespace(
frozenset(['{http://iec.ch/TC57/2013/CIM-schema-cim16#}StaticVarCompensator']),
dummy_nsmap) == ["StaticVarCompensator"]
def test_get_class_names_md(dummy_nsmap):
assert shorten_namespace(
frozenset(["{http://iec.ch/TC57/61970-552/ModelDescription/1#}FullModel"]),
dummy_nsmap) == ["md_FullModel"]
def test_get_class_names_entsoe(dummy_nsmap):
assert shorten_namespace(
frozenset(['{http://entsoe.eu/CIM/SchemaExtension/3/1#}EnergySchedulingType']),
dummy_nsmap) == ["entsoe_EnergySchedulingType"]
PK ! Q $ cimpyorm/Test/test_data_integrity.pydef test_num_of_elements(load_test_db):
session, m = load_test_db
assert session.query(m.Terminal).count() == 144
def test_native_properties(load_test_db):
session, m = load_test_db
assert isinstance(session.query(m.ACDCConverter.idleLoss).filter(
m.ACDCConverter.id == "_0f05e270-37ea-471d-89fe-aee8a55b932b"
).one()[0], float)
assert session.query(m.ACDCConverter.idleLoss).filter(
m.ACDCConverter.id == "_0f05e270-37ea-471d-89fe-aee8a55b932b"
).one() == (1.0,)
def test_inherited_properties(load_test_db):
session, m = load_test_db
assert session.query(m.Terminal.name).filter(
m.Terminal.id == "_800ada75-8c8c-4568-aec5-20f799e45f3c"
).one() == ("BE-Busbar_2_Busbar_Section",)
def test_relationship(load_test_db):
session, m = load_test_db
assert isinstance(session.query(m.Terminal).filter(
m.Terminal.id == "_800ada75-8c8c-4568-aec5-20f799e45f3c"
).one().ConnectivityNode, m.ConnectivityNode)
def test_alter_data(load_test_db):
session, m = load_test_db
obj = session.query(m.IdentifiedObject).first()
obj.entsoe_energyIdentCodeEic = "YetAnotherCode"
session.commit()
assert session.query(m.IdentifiedObject).first().entsoe_energyIdentCodeEic == "YetAnotherCode"
PK ! x[۠6 6 % cimpyorm/Test/test_loadRDFS_pytest.pyimport os
import pytest
from cimpyorm.auxiliary import get_path, find_rdfs_path
@pytest.mark.parametrize("Version", [(16)])
def test_find_valid_rdfs_version(Version):
try:
os.path.isdir(get_path("SCHEMAROOT"))
except KeyError:
pytest.skip(f"Schema folder not configured")
version = f"{Version}"
rdfs_path = find_rdfs_path(version)
assert os.path.isdir(rdfs_path) and os.listdir(rdfs_path)
@pytest.mark.parametrize("Version", [(9), (153), ("foo"), ("ba")])
def test_find_invalid_rdfs_version(Version):
try:
os.path.isdir(get_path("SCHEMAROOT"))
except KeyError:
pytest.skip(f"Schema folder not configured")
with pytest.raises((ValueError, NotImplementedError)) as ex_info:
version = f"{Version}"
find_rdfs_path(version)
print(ex_info)
PK ! cimpyorm/Test/test_metadata.pydef test_parse_meta(acquire_db, dummy_source):
_, session = acquire_db
assert dummy_source.tree
assert dummy_source.nsmap == {'cim': 'http://iec.ch/TC57/2013/CIM-schema-cim16#',
'entsoe': 'http://entsoe.eu/CIM/SchemaExtension/3/1#',
'md': 'http://iec.ch/TC57/61970-552/ModelDescription/1#',
'rdf': 'http://www.w3.org/1999/02/22-rdf-syntax-ns#'}
assert dummy_source.cim_version == "16"
PK ! 'yw/ cimpyorm/Test/test_parser.pyimport pytest
def test_single_object(cgmes_schema):
import lxml.etree as et
ACL = cgmes_schema.model.classes.ACLineSegment
literal = '' \
'' \
' ' \
' BE-Line_1' \
' ' \
' 2.200000' \
' 68.200000' \
' 0.0000829380' \
' 22.000000' \
' 0.0000308000' \
' false' \
' ' \
' 6.600000' \
' 204.600000' \
' 0.0000262637' \
' 0.0000308000' \
' 160.0000000000' \
' BE-L_1' \
' 10T-AT-DE-000061' \
' 10T-AT-DE-000061' \
' 17086487-56ba-4979-b8de-064025a6b4da' \
' ' \
''
map = {'mRID': '17086487-56ba-4979-b8de-064025a6b4da',
'name': 'BE-Line_1',
'description': '10T-AT-DE-000061',
'entsoe_energyIdentCodeEic': '10T-AT-DE-000061',
'entsoe_shortName': 'BE-L_1',
'EquipmentContainer_id': '_2b659afe-2ac3-425c-9418-3383e09b4b39',
'aggregate': False,
'BaseVoltage_id': '_7891a026ba2c42098556665efd13ba94',
'length': 22.0,
'bch': 8.2938e-05,
'gch': 3.08e-05,
'r': 2.2,
'x': 68.2,
'b0ch': 2.62637e-05,
'g0ch': 3.08e-05,
'r0': 6.6,
'shortCircuitEndTemperature': 160.0, 'x0': 204.6}
assert ACL.parse_values(et.fromstring(literal.encode("UTF-8"))[0], cgmes_schema.session)[0] == map
one_node = \
''\
''\
'TOP_NET_1'\
''\
''\
'7f28263d-4f21-c942-be2e-3c6b8d54c546'\
''\
''
multi_node = \
''\
''\
'TOP_NET_1'\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
''\
'7f28263d-4f21-c942-be2e-3c6b8d54c546'\
''\
''
@pytest.mark.parametrize("literal", [one_node, multi_node], ids=["single_property_node", "multiple_property_nodes"])
def test_m2m_rel(cgmes_schema, literal):
import lxml.etree as et
TI = cgmes_schema.model.classes.TopologicalIsland
insertable = TI.parse_values(et.fromstring(literal.encode("UTF-8"))[0], cgmes_schema.session)[1][0]
values = insertable.parameters
assert "TopologicalIsland_id" in values[0].keys()
assert "TopologicalNode_id" in values[0].keys()
assert "_f6ee76f7-3d28-6740-aa78-f0bf7176cdad" in [value["TopologicalNode_id"] for value in values]
assert len(values) == 20PK ! h h cimpyorm/Test/test_schema.pyfrom cimpyorm.Model.Elements import CIMClass
def test_persisted_classes(cgmes_schema):
schema = cgmes_schema
# Make sure we have all CIMClasses
assert len(schema.Elements["CIMClass"]) == 397
assert schema.Elements["CIMClass"]["ACLineSegment"] is \
schema.session.query(CIMClass).filter(CIMClass.name == "ACLineSegment").one()
def test_summary(cgmes_schema):
schema = cgmes_schema
assert schema.model.classes.ACLineSegment.property_table().shape == (27, 8)
def test_description_CIMClass(cgmes_schema):
from cimpyorm import describe
describe(cgmes_schema.model.classes.TopologicalNode)
cgmes_schema.model.classes.TopologicalNode.describe()
def test_description_parseable(cgmes_schema):
from cimpyorm import describe
describe(cgmes_schema.model.TopologicalNode)
cgmes_schema.model.TopologicalNode.describe()
PK ! SF F cimpyorm/Test/test_xml_merge.pyimport pytest
import lxml.etree as et
import os
from cimpyorm.auxiliary import log, get_path, parseable_files, merge
schemata = []
datasets = []
try:
SCHEMAROOT = get_path("SCHEMAROOT")
if os.path.isdir(SCHEMAROOT) and os.listdir(SCHEMAROOT):
schemata = [os.path.join(SCHEMAROOT, f"CIM{version}")
for version in [16]]
except KeyError:
pass
try:
DATASETROOT = get_path("DATASETROOT")
if os.path.isdir(os.path.join(DATASETROOT)) and os.listdir(os.path.join(DATASETROOT)):
datasets = [os.path.join(DATASETROOT, dir_) for dir_ in os.listdir(os.path.join(DATASETROOT))
if os.path.isdir(os.path.join(DATASETROOT, dir_))]
except KeyError:
pass
tested_directories = schemata + datasets
@pytest.mark.parametrize("path", tested_directories)
def test_count_merged_elements(path):
"""
Make sure no information is lost during XMLMerge (Equal number of elements).
:param path: Path to folder containing xml files.
:return:
"""
files = os.listdir(path)
files = [os.path.join(path, file) for file in files if
file.endswith(".xml") or file.endswith(".rdf")]
elements = 0
for xmlfile in files:
elements += len(et.parse(xmlfile).getroot())
tree = merge(path)
assert len(tree.getroot()) == elements
@pytest.mark.parametrize("path", tested_directories)
def test_count_properties(path):
files = os.listdir(path)
files = [os.path.join(path, file) for file in files if
file.endswith(".xml") or file.endswith(".rdf")]
properties_unmerged = 0
for xmlfile in files:
for node in et.parse(xmlfile).getroot():
properties_unmerged += len(node)
tree = merge(path)
properties_merged = sum(len(node) for node in tree.getroot())
assert properties_merged == properties_unmerged
@pytest.mark.parametrize("path", tested_directories)
def test_merged_nsmaps(path):
expected = {}
for file in parseable_files(path):
for key, value in et.parse(file).getroot().nsmap.items():
expected[key] = value
tree = merge(path)
log.info(f"{len(expected.keys())} entries expected in nsmap. {len(tree.getroot().nsmap.keys())} found")
log.debug(f"Expected: {expected.keys()}")
log.debug(f"Found: {tree.getroot().nsmap.keys()}")
assert tree.getroot().nsmap == expected
PK ! y]} } cimpyorm/__init__.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
"""
cimpyorm creates ORM representations of CIM datasets.
This module sets up and provides configuration and imports.
"""
# pylint: disable=ungrouped-imports
import os
from cimpyorm.auxiliary import log, get_path, _CONFIGPATH, CONFIG, _TESTROOT, _PACKAGEROOT
if not os.path.isfile(_CONFIGPATH):
with open(_CONFIGPATH, "w+") as f:
# Update config.ini
CONFIG.write(f)
try:
import pytest
def test_all(runslow=False):
if runslow:
pytest.main([os.path.join(_TESTROOT), "--runslow"])
else:
pytest.main([os.path.join(_TESTROOT)])
except ModuleNotFoundError:
pass
try:
# See if we already know a schemaroot
CONFIG["Paths"]["SCHEMAROOT"] = get_path("SCHEMAROOT")
if not os.path.isdir(CONFIG["Paths"]["SCHEMAROOT"]):
# Is schemaroot an actual directory?
log.warning(f"Invalid schema path in configuration.")
raise NotADirectoryError
except (KeyError, NotADirectoryError):
if os.path.isdir(os.path.join(_PACKAGEROOT, "res", "schemata")):
# Look in the default path
CONFIG["Paths"]["SCHEMAROOT"] = os.path.join(_PACKAGEROOT, "res", "schemata")
log.info(f"Found schemata in default location.")
else:
# Ask user to configure
log.warning(f"No schemata configured. Use cimpyorm.configure(path_to_schemata) to set-up.")
from cimpyorm.api import configure
try:
# See if we already know a datasetroot
CONFIG["Paths"]["DATASETROOT"] = get_path("DATASETROOT")
if not os.path.isdir(CONFIG["Paths"]["DATASETROOT"]):
# Is datasetroot an actual directory?
log.warning(f"Invalid dataset path in configuration.")
raise NotADirectoryError
except (KeyError, NotADirectoryError):
if os.path.isdir(os.path.join(_PACKAGEROOT, "res", "datasets")):
# Look in the default path
CONFIG["Paths"]["DATASETROOT"] = os.path.join(_PACKAGEROOT, "res", "datasets")
log.info(f"Found datasets in default location.")
else:
# Ask user to configure
log.info(f"No datasets configured. Use cimpyorm.configure(path_to_datasets) to set-up.")
from cimpyorm.api import configure
with open(_CONFIGPATH, "w+") as f:
# Update config.ini
CONFIG.write(f)
def describe(element, fmt="psql"):
element.describe(fmt)
try:
from cimpyorm.api import parse, load, describe # pylint: disable=wrong-import-position
from cimpyorm.Model.Schema import Schema # pylint: disable=wrong-import-position
except ModuleNotFoundError:
log.warning(f"Unfulfilled requirements. parse and load are not available.")
PK ! /TE cimpyorm/api.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
import os
from pathlib import Path
import configparser
from typing import Union, Tuple
from argparse import Namespace
from sqlalchemy.orm.session import Session
from cimpyorm.auxiliary import log, get_path
from cimpyorm.Model.Schema import Schema
from cimpyorm.backends import SQLite, Engine, InMemory
def configure(schemata: Union[Path, str] = None, datasets: Union[Path, str] = None):
"""
Configure paths to schemata or update the DATASETROOT used for tests.
:param schemata: Path to a folder containing CIM schema descriptions.
:param datasets: Path to a folder containing test datasets.
"""
config = configparser.ConfigParser()
config.read(get_path("CONFIGPATH"))
if schemata:
config["Paths"]["SCHEMAROOT"] = os.path.abspath(schemata)
if datasets:
config["Paths"]["DATASETROOT"] = os.path.abspath(datasets)
with open(get_path("CONFIGPATH"), 'w') as configfile:
config.write(configfile)
def load(path_to_db: Union[Engine, str], echo: bool = False) -> Tuple[Session, Namespace]:
"""
Load an already parsed database from disk or connect to a server and yield a database session to start querying on
with the classes defined in the model namespace.
Afterwards, the database can be queried using SQLAlchemy query syntax, providing the CIM classes contained in the
:class:`~argparse.Namespace` return value.
:param path_to_db: Path to the cim snapshot or a :class:`~cimpyorm.backend.Engine`.
:param echo: Echo the SQL sent to the backend engine (SQLAlchemy option).
:return: :class:`sqlalchemy.orm.session.Session`, :class:`argparse.Namespace`
"""
import cimpyorm.Model.Schema as Schema
from cimpyorm.Model import Source
if isinstance(path_to_db, Engine):
_backend = path_to_db
_backend.echo = _backend.echo or echo
elif os.path.isfile(path_to_db):
_backend = SQLite(path_to_db, echo)
else:
raise NotImplementedError(f"Unable to connect to database {path_to_db}")
session = _backend.session
_backend.reset()
_si = session.query(Source.SourceInfo).first()
v = _si.cim_version
log.info(f"CIM Version {v}")
schema = Schema.Schema(session)
schema.init_model(session)
model = schema.model
return session, model
def parse(dataset: Union[str, Path], backend: Engine = SQLite()) -> Tuple[Session, Namespace]:
"""
Parse a database into a database backend and yield a database session to start querying on with the classes defined
in the model namespace.
Afterwards, the database can be queried using SQLAlchemy query syntax, providing the CIM classes contained in the
:class:`~argparse.Namespace` return value.
:param dataset: Path to the cim snapshot.
:param backend: Database backend to be used (defaults to a SQLite on-disk database in the dataset location).
:return: :class:`sqlalchemy.orm.session.Session`, :class:`argparse.Namespace`
"""
from cimpyorm import Parser
backend.update_path(dataset)
# Reset database
backend.drop()
backend.reset()
# And connect
engine, session = backend.connect()
files = Parser.get_files(dataset)
from cimpyorm.Model.Source import SourceInfo
sources = frozenset([SourceInfo(file) for file in files])
session.add_all(sources)
session.commit()
cim_version = Parser.get_cim_version(sources)
schema = Schema(version=cim_version, session=session)
backend.generate_tables(schema)
log.info(f"Parsing data.")
entries = Parser.merge_sources(sources)
elements = Parser.parse_entries(entries, schema)
log.info(f"Passing {len(elements):,} objects to database.")
session.bulk_save_objects(elements)
session.flush()
log.debug(f"Start commit.")
session.commit()
log.debug(f"Finished commit.")
if engine.dialect.name == "mysql":
log.debug("Enabling foreign key checks in mysql database.")
session.execute("SET foreign_key_checks='ON'")
log.info("Exit.")
model = schema.model
return session, model
def docker_parse() -> None:
"""
Dummy function for parsing in shared docker tmp directory.
"""
parse(r"/tmp")
def describe(element, fmt: str = "psql") -> None:
"""
Give a description of an object.
:param element: The element to describe.
:param fmt: Format string for tabulate package.
"""
try:
element.describe(fmt)
except AttributeError:
print(f"Element of type {type(element)} doesn't provide descriptions.")
if __name__ == "__main__":
root = get_path("DATASETROOT")
# db_session, m = parse([os.path.abspath(os.path.join(root, folder)) for folder in os.listdir(root) if
# os.path.isdir(os.path.join(root, folder)) or
# os.path.join(root, folder).endswith(".zip")])
db_session, m = parse(os.path.join(get_path("DATASETROOT"), "FullGrid"), InMemory())
print(db_session.query(m.IdentifiedObject).first().name) # pylint: disable=no-member
db_session.close()
PK ! / cimpyorm/auxiliary.py#
# Copyright (c) 2018 - 2018 Thomas Offergeld (offergeld@ifht.rwth-aachen.de)
# Institute for High Voltage Technology
# RWTH Aachen University
#
# This module is part of cimpyorm.
#
# cimpyorm is licensed under the BSD-3-Clause license.
# For further information see LICENSE in the project's root directory.
#
import os
from functools import lru_cache
from typing import Collection, Iterable
from pathlib import Path
import configparser
import logging
from zipfile import ZipFile
from itertools import chain
class HDict(dict):
"""Provide a hashable dict for use as cache key"""
def __hash__(self):
return hash(frozenset(self.items()))
def chunks(l: Collection, n: int) -> Iterable:
"""
Iteratively yield from an iterable at most n elements.
:param l: The iterable to yield from.
:param n: The maximum number of elements
:return: Yield elements from the iterable.
"""
for i in range(0, len(l), n):
yield l[i:i+n]
class CustomFormatter(logging.Formatter):
"""
Elapsed time logging formatter.
"""
def formatTime(self, record, datefmt=None):
return f"{round(record.relativeCreated/1000)}." \
f"{round(record.relativeCreated%1000)}"
log = logging.getLogger("cim_orm")
if not log.handlers:
log.setLevel(logging.INFO)
handler = logging.StreamHandler()
log.addHandler(handler)
formatter = CustomFormatter(fmt='T+%(asctime)10ss:%(levelname)8s: %(message)s')
handler.setFormatter(formatter)
log.debug("Logger configured.")
CONFIG = configparser.ConfigParser()
# Set default paths
CONFIG["Paths"] = {"PACKAGEROOT": Path(os.path.abspath(__file__)).parent,
"TESTROOT": os.path.join(Path(os.path.abspath(__file__)).parent, "Test"),
"CONFIGPATH": os.path.join(Path(os.path.abspath(__file__)).parent, "config.ini")}
_TESTROOT = CONFIG["Paths"]["TESTROOT"]
_PACKAGEROOT = CONFIG["Paths"]["PACKAGEROOT"]
_CONFIGPATH = CONFIG["Paths"]["CONFIGPATH"]
def get_path(identifier: str) -> str:
"""
Get the requested path from the package config.
:param identifier: Path-type identifier.
:return:
"""
config = configparser.ConfigParser()
config.read(_CONFIGPATH)
return config["Paths"][identifier]
def merge(source_path):
"""
Merges several ElementTrees into one.
:return: Merged Elementtree
"""
from lxml import etree as et
path = source_path
files = parseable_files(path)
base = et.parse(files[0])
root = base.getroot()
nsmap = root.nsmap
for file in files[1:]:
tree = et.parse(file)
for key, value in tree.getroot().nsmap.items():
if key in nsmap and value != nsmap[key]:
log.error("Incompatible namespaces in schema files")
nsmap[key] = value
for child in tree.getroot():
root.append(child)
tree = et.ElementTree(root)
et.cleanup_namespaces(tree, top_nsmap=nsmap, keep_ns_prefixes=nsmap.keys())
return tree
def parseable_files(path):
"""
Identify the parseable files within a directory (.xml/.rdf)
:param path: path to the directory
:return: list of files
"""
if path.endswith(".rdf") or path.endswith(".xml"):
files = [path]
elif path.endswith(".zip"):
dir_ = ZipFile(path, "r")
files = [dir_.open(name) for name in dir_.namelist() if name.endswith(
".xml") or name.endswith(".rdf")]
else:
files = os.listdir(os.path.abspath(path))
files = [os.path.join(path, file) for file in files if
file.endswith(".xml") or file.endswith(".rdf")]
if not files:
# There are no xml files in the folder - assume the first .zip
# is the zipped CIM
files = [os.path.join(path, file) for file in os.listdir(path) if
file.endswith(".zip") or file.endswith(".rdf")]
dir_ = ZipFile(files[0])
files = [dir_.open(name) for name in dir_.namelist() if name.endswith(
".xml") or name.endswith(".rdf")]
return files
@lru_cache()
def shorten_namespace(elements, nsmap):
"""
Map a list of XML tag class names on the internal classes (e.g. with shortened namespaces)
:param classes: list of XML tags
:param nsmap: XML nsmap
:return: List of mapped names
"""
names = []
_islist = True
if not isinstance(elements, (list, frozenset)):
elements = [elements]
_islist = False
for el in elements:
for key, value in nsmap.items():
if value in el:
if key == "cim":
names.append(el.split(value[-1]+"}")[-1])
else:
names.append(el.replace("{"+value+"}", key+"_"))
if el.startswith("#"):
names.append(el.split("#")[-1])
if not _islist and len(names) == 1:
names = names[0]
return names
def merge_descriptions(descriptions):
"""
Returns the descriptions for a CIM class merged into only one description
:param descriptions: Iterable of the descriptions
:return: Result of the merge
"""
if isinstance(descriptions, list):
description = descriptions[0]
# pylint: disable=expression-not-assigned
[description.append(value) for value in list(chain(*[list(descr) for descr in descriptions]))]
else:
description = descriptions
return description
def find_rdfs_path(version):
"""
Attempt to identify which schema to use from the model file header.
:param version: The CIM version.
:return: Path to the schema files on local file system
"""
if version:
log.info(f"Using CIM Version {version}.")
else:
raise ValueError(f"Failed to determine CIM Version")
if len(version) > 2:
raise ValueError(f"Unexpected CIM Version (v={version}).")
try:
rdfs_path = os.path.join(get_path("SCHEMAROOT"), f"CIM{version}")
except KeyError:
log.critical(f"Schema not defined.")
raise RuntimeError(f"Couldn't find CIM schemata. "
f"Please configure a schema repository using cimpyorm.configure.")
if not os.path.isdir(rdfs_path):
raise NotImplementedError(f"Unknown CIM Version for (v={version}). Add to "
f"schemata")
return rdfs_path
PK ! a6$ $ cimpyorm/backends.pyimport os
from importlib import reload
from abc import ABC
import sqlalchemy as sa
from sqlalchemy.engine import Engine as SA_Engine
from sqlalchemy.orm.session import Session as SA_Session
from sqlalchemy.exc import OperationalError, InternalError
from sqlalchemy.orm import sessionmaker
from sqlalchemy.ext.declarative import declarative_base
from networkx import bfs_tree
# pylint: disable=too-many-arguments
import cimpyorm.Model.auxiliary as aux
from cimpyorm.auxiliary import log
class Engine(ABC):
def __init__(self, dialect=None, echo=False, driver=None, path=None):
self.dialect = dialect
self.echo = echo
self.driver = driver
self.path = path
self._engine = None
@property
def engine(self) -> SA_Engine:
"""
:param echo:
:param database:
:return:
"""
if not self._engine:
log.info(f"Database: {self.path}")
engine = self._connect_engine()
self._engine = engine
return self._engine
@property
def session(self) -> SA_Session:
Session = sessionmaker(bind=self.engine)
session = Session()
return session
def connect(self):
return self.engine, self.session
def update_path(self, path):
pass
def _prefix(self):
if self.driver:
return f"{self.dialect}+{self.driver}"
else:
return f"{self.dialect}"
def _connect_engine(self):
raise NotImplementedError
def drop(self):
raise NotImplementedError
def reset(self) -> None:
"""
Reset the table metadata for declarative classes.
:param engine: A sqlalchemy db-engine to reset
:return: None
"""
import cimpyorm.Model.Elements as Elements
import cimpyorm.Model.Schema as Schema
import cimpyorm.Model.Source as Source
aux.Base = declarative_base(self.engine)
reload(Source)
reload(Elements)
reload(Schema)
Source.SourceInfo.metadata.create_all(self.engine)
Elements.SchemaElement.metadata.create_all(self.engine)
Schema.SchemaInfo.metadata.create_all(self.engine)
def generate_tables(self, schema):
g = schema.inheritance_graph
hierarchy = list(bfs_tree(g, "__root__"))
hierarchy.remove("__root__")
log.info(f"Creating map prefixes.")
for c in hierarchy:
c.class_.compile_map(c.nsmap)
# ToDo: create_all is quite slow, maybe this can be sped up. Currently low priority.
log.info(f"Creating table metadata.")
for child in g["__root__"]:
child.class_.metadata.create_all(self.engine)
log.info(f"Backend model ready.")
class SQLite(Engine):
def __init__(self, path="out.db", echo=False, driver=None, dataset_loc=None):
"""
Default constructor for SQLite backend instance
:param path: Storage location for the .db-file (default: "out.db" in cwd)
:param echo: SQLAlchemy "echo" parameter (default: False)
:param driver: Python SQLite driver (default: sqlite3)
:param dataset_loc: Dataset location used to automatically determine storage location (in the dataset folder)
"""
self.dialect = "sqlite"
super().__init__(self.dialect, echo, driver, path)
def drop(self):
try:
os.remove(self.path)
log.info(f"Removed old database {self.path}.")
self._engine = None
except FileNotFoundError:
pass
@property
def engine(self):
return super().engine
def update_path(self, path):
if path is None:
out_dir = os.getcwd()
elif isinstance(path, list):
try:
out_dir = os.path.commonpath([os.path.abspath(path) for path in path])
except ValueError:
# Paths are on different drives - default to cwd.
log.warning(f"Datasources have no common root. Database file will be saved to {os.getcwd()}")
out_dir = os.getcwd()
else:
out_dir = os.path.abspath(path)
if not os.path.isabs(self.path):
if os.path.isdir(out_dir):
db_path = os.path.join(out_dir, self.path)
else:
db_path = os.path.join(os.path.dirname(out_dir), "out.db")
else:
db_path = os.path.abspath(self.path)
self.path = db_path
def _connect_engine(self):
# ToDo: Disabling same_thread check is only treating the symptoms, however, without it, property changes
# can't be committed
return sa.create_engine(f"{self._prefix()}:///{self.path}",
echo=self.echo, connect_args={"check_same_thread": False})
class InMemory(Engine):
def __init__(self, echo=False, driver=None):
"""
Default constructor for In-Memory-SQLite instances
:param echo: SQLAlchemy "echo" parameter (default: False)
:param driver: Python SQLite driver (default: sqlite3)
"""
self.dialect = "sqlite"
super().__init__(self.dialect, echo, driver)
def drop(self):
log.info(f"Removed old database {self.path}.")
self._engine = None
def _connect_engine(self):
# ToDo: Disabling same_thread check is only treating the symptoms, however, without it, property changes
# can't be committed
return sa.create_engine(f"{self._prefix()}:///:memory:",
echo=self.echo, connect_args={"check_same_thread": False})
class ClientServer(Engine):
def __init__(self, username=None, password=None, driver=None,
host=None, port=None, path=None, echo=False):
super().__init__(None, echo, driver, path)
self.username = username
self.password = password
self.hostname = host
self.port = port
@property
def remote_path(self):
if self.path:
return f"{self.host}/{self.path}"
else:
return self.host
@property
def host(self):
return f"{self.hostname}:{self.port}"
def drop(self):
try:
log.info(f"Dropping database {self.path} at {self.host}.")
self.engine.execute(f"DROP DATABASE {self.path};")
except OperationalError:
pass
self._engine = None
def _credentials(self):
return f"{self.username}:{self.password}"
def _connect_engine(self):
engine = sa.create_engine(
f"{self._prefix()}://{self._credentials()}@{self.remote_path}", echo=self.echo)
try:
engine.connect()
# Pymysql error is raised as InternalError
except (OperationalError, InternalError):
engine = sa.create_engine(
f"{self._prefix()}://{self._credentials()}@{self.host}", echo=self.echo)
engine.execute(f"CREATE SCHEMA {self.path} DEFAULT CHARACTER SET utf8 COLLATE "
f"utf8_bin;")
engine = sa.create_engine(
f"{self._prefix()}://{self._credentials()}@{self.remote_path}", echo=self.echo)
return engine
class MariaDB(ClientServer):
def __init__(self, username="root", password="", driver="pymysql",
host="127.0.0.1", port=3306, path="cim", echo=False):
"""
Default constructor for MariaDB backend instance
:param username: Username for the MariaDB database (default: root)
:param password: Password for username (at) MariaDB database (default: "")
:param driver: Python MariaDB driver (default: mysqlclient)
:param host: Database host (default: localhost)
:param port: Database port (default: 3306)
:param path: Database name (default: "cim")
:param echo: SQLAlchemy "echo" parameter (default: False)
"""
super().__init__(username, password, driver, host,
port, path, echo)
self.dialect = "mysql"
@property
def session(self):
session = super().session
log.debug("Deferring foreign key checks in mysql database.")
session.execute("SET foreign_key_checks='OFF'")
return session
class MySQL(ClientServer):
def __init__(self, username="root", password="", driver="pymysql",
host="127.0.0.1", port=3306, path="cim", echo=False):
"""
Default constructor for MySQL backend instance
:param username: Username for the MySQL database (default: root)
:param password: Password for username (at) MySQL database (default: "")
:param driver: Python MariaDB driver (default: pymysql)
:param host: Database host (default: localhost)
:param port: Database port (default: 3306)
:param path: Database name (default: "cim")
:param echo: SQLAlchemy "echo" parameter (default: False)
"""
super().__init__(username, password, driver, host,
port, path, echo)
self.dialect = "mysql"
@property
def session(self):
session = super().session
log.debug("Deferring foreign key checks in mysql database.")
session.execute("SET foreign_key_checks='OFF'")
return session
PK ! &Pq q cimpyorm/res/LICENSEThe content of the "datasets" and "schemata" folder is owned and distributed by
ENTSO-E and is included for the users' convenience. At present, the files are
available for download for the ENTSO-E's CGMES website.
It should be noted, that the test cases should always be considered as such and
come with the limitations described in the documentation available online.PK ! :* = cimpyorm/res/datasets/FullGrid/20171002T0930Z_1D_BE_SSH_4.xml
2015-12-15T10:10:10
2017-10-02T09:30:00Z
4
CGMES Conformity Assessment: FullGridTestConfiguration (Node Breaker MAS BE with Short Circuit). The model is owned by ENTSO-E and is provided by ENTSO-E “as it is”. To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
http://elia.be/CAS2.0/FullGridTestConfiguration
http://entsoe.eu/CIM/SteadyStateHypothesis/1/1
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true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
true
0e+000
0e+000
0
0e+000
150.000000
0e+000
0e+000
1.000000
-40.000000
0e+000
150.000000
0
150.000000
0e+000
0e+000
0e+000
1.000000
40.000000
0e+000
0e+000
PK ! C ] ] < cimpyorm/res/datasets/FullGrid/20171002T0930Z_1D_BE_SV_4.xml
2015-12-15T10:10:10
2017-10-02T09:30:00Z
4
CGMES Conformity Assessment: FullGridTestConfiguration (Node Breaker MAS BE with Short Circuit). The model is owned by ENTSO-E and is provided by ENTSO-E “as it is”. To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
http://elia.be/CAS2.0/FullGridTestConfiguration
http://entsoe.eu/CIM/StateVariables/4/1
144.091321
28.298917
126.387329
150.000000
0.311637
500.000000
26.278693
145.685567
126.332508
151.250000
0.311636
500.000000
DC_TOP_NET_1
4c6e15a8-b830-9a44-bb89-9bd49073d604
0.0
0.0
0e+000
-126.787790
0
0
-90.000000
103.893000
-118.000000
-68.351957
0e+000
-42.070633
-118.000000
-68.351957
-33.718508
2.598975
0e+000
-330.750000
0
0
0
0
0
0
1.184602
-59.230078
0
0
1.000000
0e+000
-34.542367
1.292361
200.000000
50.000000
-43.627121
78.432952
0
0
200.000000
90.000000
0
0
-118.000000
-68.351957
-40.273274
83.928997
0
0
-83.922866
147.271512
0
0
-118.000000
-68.351957
1
1
1
1
1
false
5
17
21
-2
7
4
15
7
6
4
10
226.136561
-8.260120
225.808184
5.724049
124.427328
-10.499000
225.658343
-8.734640
411.770499
-6.486570
115.500000
-8.632430
413.215265
-6.634090
225.658343
-8.734640
21.987000
-6.320160
10.795720
-6.212020
126.332508
-12.196600
226.033049
-8.267930
115.500000
-8.632430
226.006478
-6.149480
124.334501
12.534110
225.471858
-6.216820
411.500287
-6.474900
413.589732
-6.665390
224.157402
-3.639090
413.589732
-8.734640
115.500000
-8.632430
115.500000
-8.632430
126.387329
-4.880770
225.622398
-8.751450
115.500000
-8.632430
TOP_NET_1
7f28263d-4f21-c942-be2e-3c6b8d54c546
0
124.334501
124.334501
150.000000
3.333385
962.342430
0
124.427328
124.427328
152.405856
3.333380
962.342430
PK ! i۪ < cimpyorm/res/datasets/FullGrid/20171002T0930Z_1D_BE_TP_4.xml
2015-12-15T10:10:10
2017-10-02T09:30:00Z
4
CGMES Conformity Assessment: FullGridTestConfiguration (Node Breaker MAS BE with Short Circuit). The model is owned by ENTSO-E and is provided by ENTSO-E “as it is”. To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
http://elia.be/CAS2.0/FullGridTestConfiguration
http://entsoe.eu/CIM/Topology/4/1
BE_DC1
BE_DC1
357fb476-d752-4e74-b673-dc8ad95e4225
BE_DC1
00X-BE-BE-000518
BE_DC2
BE_DC2
146ccb96-a5b6-4973-b41f-0b0cdabd67a5
BE_DC2
00X-BE-BE-000519
DC_Ground1
DC_Ground1
0bc1fb88-9b0b-434e-a7a7-aef9a177387d
DC_Ground1
00X-BE-BE-000520
DC_Ground2
DC_Ground2
7e602b57-bc66-42b5-b230-4fbd10d6e920
DC_Ground2
00X-BE-BE-000521
HVDC1_1
HVDC1_1
e468941a-d3ca-4cdc-909d-1005000d52fe
HVDC1_1
00X-BE-BE-000522
HVDC1_2
HVDC1_2
b1db3355-4f8e-8344-baed-f610846576aa
HVDC1_2
00X-BE-BE-000523
HVDC1_3
HVDC1_3
d85a56e0-f41f-9941-90c7-14a76ecbabf6
HVDC1_3
00X-BE-BE-000524
HVDC1_4
HVDC1_4
a4890562-1110-194d-8b6d-efe221be128e
HVDC1_4
00X-BE-BE-000525
HVDC1_5
HVDC1_5
6493024f-5275-8641-a94b-b32f279f6209
HVDC1_5
00X-BE-BE-000526
HVDC1_6
HVDC1_6
ef3250c1-a5c6-da48-b61c-d5859a215255
HVDC1_6
00X-BE-BE-000527
HVDC1_Ground
HVDC1_Ground
5ee57d5c-e4f8-4fd0-bff5-e751d816c5f9
HVDC1_Ground
00X-BE-BE-000528
HVDC2_1
HVDC2_1
8e17e2d1-8b97-492f-a5bd-65b1b350f40f
HVDC2_1
00X-BE-BE-000529
HVDC2_Ground
HVDC2_Ground
ead7aff5-6110-4863-9a8d-b9071b872102
HVDC2_Ground
00X-BE-BE-000530
BE-Busbar_10
BBRUS151; BGENT_51
BE-B_10
00X-BE-BE-000875
f6ee76f7-3d28-6740-aa78-f0bf7176cdad
BE-Busbar_11
BBRUS151; BGENT_51
BE-B_11
00X-BE-BE-000876
514fa0d5-a432-5743-8204-1c8518ffed76
BE-Busbar_12
BBRUS_21; this is UCTE code
BE-B_12
00X-BE-BE-000877
ac279ca9-c4e2-0145-9f39-c7160fff094d
BE-Busbar_2
BBRUS_21; this is UCTE code
BE-B_2
00X-BE-BE-000878
f70f6bad-eb8d-4b8f-8431-4ab93581514e
BE-Busbar_4
BGENT_71; This is the old UCTE code from UCTE DEF
BE-B_4
00X-BE-BE-000879
a81d08ed-f51d-4538-8d1e-fb2d0dbd128e
BE-Busbar_5
BGENT_72; this is old code
BE-B_5
00X-BE-BE-000880
f96d552a-618d-4d0c-a39a-2dea3c411dee
BE-Busbar_6
BBRUS151; BGENT_51
BE-B_6
00X-BE-BE-000881
5c74cb26-ce2f-40c6-951d-89091eb781b6
BE-Busbar_7
BBRUS151; BGENT_51
BE-B_6
00X-BE-BE-000882
4c66b132-0977-1e4c-b9bb-d8ce2e912e35
BE-Busbar_8
BBRUS_21; this is UCTE code
BE-B_8
00X-BE-BE-000883
52dc7463-7646-b244-8b12-eb57fbd30eab
BE-Busbar_9
BBRUS151; BGENT_51
BE-B_9
00X-BE-BE-000884
c21be5da-d2a6-d94f-8dcb-92e4d6fa48a7
BE_Busbar_HVDC1
BE_Busbar_HVDC1
Busbar_HVDC1
00X-BE-BE-000889
ac772dd8-7910-443f-8af0-a7fca0fb57f9
BE_Busbar_HVDC2
BE_Busbar_HVDC2
Busbar_HVDC2
00X-BE-BE-000890
b01fe92f-68ab-4123-ae45-f22d3e8daad1
BE_HVDC_BUS2
BE_HVDC_BUS2
BE_HVDC_BUS2
00X-BE-BE-000885
d3d9c515-2ddb-436a-bf17-2f8be2394de3
BE_PCC1
10T-AT-DE-00017X
BE_PCC1
10T-AT-DE-00017X
902e51fc-8487-4d9d-ba3a-7dcfcfeef4d1
BE_PCC1
10T-AT-DE-00017X
BE_PCC1
10T-AT-DE-00017X
9f1860f9-2110-4a36-b0a0-f75126040d29
BE_PCC2
10T-AT-DE-00017X
BE_PCC2
10T-AT-DE-00017X
3aad8a0b-d1d4-4ee2-9690-4c7106be4530
BE_PCC2
10T-AT-DE-00017X
BE_PCC2
10T-AT-DE-00017X
c142012a-b652-4c03-9c35-aa0833e71831
BE_TR_BUS2
BE_TR_BUS2
BE_TR_BUS2
00X-BE-BE-000886
e44141af-f1dc-44d3-bfa4-b674e5c953d7
BE_TR_BUS4
BE_TR_BUS4
BE_TR_BUS4
00X-BE-BE-000887
99b219f3-4593-428b-a4da-124a54630178
N1230816360
N1230816360
N1230816360
00X-BE-BE-000888
27d57afa-6c9d-4b06-93ea-8c88d14af8b1
PK ! \19
9
9 cimpyorm/res/datasets/FullGrid/20171002T0930Z_BE_EQ_4.xml
2015-12-15T10:10:10
2017-10-02T09:30:00Z
4
CGMES Conformity Assessment: FullGridTestConfiguration (Node Breaker MAS BE with Short Circuit). The model is owned by ENTSO-E and is provided by ENTSO-E “as it is”. To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
http://elia.be/CAS2.0/FullGridTestConfiguration
http://entsoe.eu/CIM/EquipmentCore/3/1
http://entsoe.eu/CIM/EquipmentOperation/3/1
http://entsoe.eu/CIM/EquipmentShortCircuit/3/1
2
Inverter
Inverter
6c9de637-7d8d-43ec-8c15-1ce8f8c67185
Inverter
00X-BE-BE-000001
3
Inverter
Inverter
c0132134-dae0-458c-b363-dd902d757140
Inverter
00X-BE-BE-000002
2
Rectifier
Rectifier
c7a8052a-90d2-46fe-8ff6-09593f29b29e
Rectifier
00X-BE-BE-000003
3
Rectifier
Rectifier
00cec451-4e32-45bc-86b3-5c1bb0288658
Rectifier
00X-BE-BE-000004
3
VSC1
VSC1
4cefd102-4e85-4d1a-b5c1-78c55cecda95
VSC1
00X-BE-BE-000005
2
VSC1
VSC1
846ca997-4c1e-4244-85a6-ad967450a2c8
VSC1
00X-BE-BE-000006
3
VSC_2
VSC_2
201a58d2-80ca-4d91-a086-d53feb5aa77b
VSC_2
00X-BE-BE-000007
2
VSC_2
VSC_2
a44c960a-3281-47a6-b064-ce88fe0139c0
VSC_2
00X-BE-BE-000008
BE-Line_1
2.200000
68.200000
0.0000829380
22.000000
0.0000308000
false
6.600000
204.600000
0.0000262637
0.0000308000
160.0000000000
BE-L_1
10T-AT-DE-000061
10T-AT-DE-000061
17086487-56ba-4979-b8de-064025a6b4da
BE-Line_2
1.935000
34.200000
0.0000424115
45.000000
0.0000675000
true
3.195000
102.600000
0.0000664447
0.0000675000
160.0000000000
BE-L_2
10T-AT-DE-00010A
10T-AT-DE-00010A
b58bf21a-096a-4dae-9a01-3f03b60c24c7
BE-Line_3
1.050000
12.000000
0.0001498540
30.000000
0.0000600000
false
3.150000
36.000000
0.0000292168
0.0000600000
160.0000000000
BE-L_3
10T-AT-DE-00008Y
10T-AT-DE-00008Y
78736387-5f60-4832-b3fe-d50daf81b0a6
BE-Line_4
0.240000
2.000000
0.0000251956
40.000000
0.0000400000
false
0.720000
6.000000
0.0000628319
0.0000400000
160.0000000000
BE-L_4
00X-BE-BE-000009
to be connected to the boundary set
ed0c5d75-4a54-43c8-b782-b20d7431630b
BE-Line_5
0.420000
6.300000
0.0000659734
35.000000
0.0000420000
false
1.260000
18.900000
0.0000340863
0.0000420000
160.0000000000
BE-L_5
10T-AT-DE-00009W
10T-AT-DE-00009W
b18cd1aa-7808-49b9-a7cf-605eaf07b006
BE-Line_6
5.203000
71.000000
0.0000200119
100.000000
0.0001200000
true
15.000000
213.000000
0.0001476549
0.0001200000
160.0000000000
BE-L_6
00X-BE-BE-000010
TYNDP project BE-4; map reference 567
ffbabc27-1ccd-4fdc-b037-e341706c8d29
BE-Line_7
4.600000
69.000000
0.0000216770
23.000000
0.0000575000
false
13.800000
207.000000
0.0000289027
0.0000575000
160.0000000000
BE-L_7
10T-AT-DE-000061
10T-AT-DE-000061
a16b4a6c-70b1-4abf-9a9d-bd0fa47f9fe4
L1230542419
0.100000
0.300000
0.0
1.000000
0.0
false
0.300000
0.900000
0.0
0.0
160.0000000000
L1230542419
00X-BE-BE-000011
L1230542419
63f6d38b-56fb-4dae-804d-9777d5f30f80
L1230542424
0.100000
0.300000
0.0
1.000000
0.0
false
0.300000
0.900000
0.0
0.0
160.0000000000
L1230542424
00X-BE-BE-000012
L1230542424
6052bacf-9eaa-4217-be91-4c7c89e92a52
L1230816345
0.100000
0.200000
0.0000010000
1.000000
0.0000010000
false
0.300000
0.600000
0.0
0.0000010000
160.0000000000
L1230816345
00X-BE-BE-000013
L1230816345
33a8eb58-e935-4b24-ab6c-f580ff1124cd
L1230816350
0.100000
0.200000
0.0000010000
1.000000
0.0000010000
false
0.300000
0.600000
0.0
0.0000010000
160.0000000000
L1230816350
00X-BE-BE-000014
L1230816350
fc2433f0-f7e7-40ce-9a5d-2294b3034454
ACCUM_1
ThreePhasePower
ACCUM_1
b4e2d11b-9fcf-2e45-bc38-62ba690da270
ACCUM_1
00X-BE-BE-000015
ACCUM_LIM_1
99
ACCUM_LIM_1
cd70d644-db01-dc42-a61a-36ff6aa9cef9
ACCUM_LIM_1
00X-BE-BE-000016
ACC_LIMSET_1
false
ACC_LIMSET_1
5c116b74-b247-9a48-9595-457da8f04217
ACC_LIMSET_1
00X-BE-BE-000017
ACC_RESET_1
ThreePhaseActivePower
true
2015-12-02T16:06:06
ACC_RESET_1
f1a80fae-db3b-dc4e-a6af-09ada6c8fa14
ACC_RESET_1
00X-BE-BE-000018
ACC_VALUE_1
AccValue_1
100
98
2015-12-02T16:06:06
ACC_VALUE_1
299d0631-d28a-644e-9ef2-8f87bbcb8585
00X-BE-BE-000019
MW_LIM_1
99
MW_LIM_1
ebddd73b-8d2e-3448-9f2e-b389dbe19044
MW_LIM_1
00X-BE-BE-000020
ANA_1
Analog_1
ANA_1
true
ThreePhaseActivePower
51eacd68-606b-0947-89c1-8a47f5726e1c
00X-BE-BE-000021
ANA_LIM_1
99
ANA_LIM_1
304d54f1-8ab8-5c47-8e24-0f2b357ea18e
ANA_LIM_1
00X-BE-BE-000022
ANA_LIMSET_1
false
ANA_LIMSET_1
cc8c01b4-d6e8-7342-a816-5586210a08de
ANA_LIMSET_1
00X-BE-BE-000023
ANA_VALUE_1
100.0
98.0
2015-12-02T16:06:06
ANA_VALUE_1
024bd190-8e29-364e-b570-329ad9f7b5d5
ANA_VALUE_1
00X-BE-BE-000024
MVA_LIM_1
999.9
MVA_LIM_1
9b5721b8-ffdd-8d49-8768-e1d3ce1a0b3f
MVA_LIM_1
00X-BE-BE-000025
ASM_1
1.2
99.99
0.99
9.99
9
0.99
true
60.00
100
0.9
225.0
true
ASM_1
2b618292-5fec-af43-ae39-c32566d0a752
ASM_1
00X-BE-BE-000026
false
10.50
Base Voltage 10.50 kV
10.50
10.50 kV
862a4658-6b03-4550-9de2-b5c413912b75
00X-BE-BE-000027
110.00
Base Voltage 110.00 kV
110.00
110.00 kV
00b17311-075f-48f6-a79b-597f42af4694
00X-BE-BE-000028
123.90
Base Voltage 123.90 kV
123.90
123.90 kV
39100880-cb7a-4a8d-9ac0-de8c6a35eb7e
00X-BE-BE-000029
125.00
Base Voltage 125.00 kV
125.00
125.00 kV
2798b33d-c534-45f2-9252-a1ea9b3247c6
00X-BE-BE-000030
21.00
Base Voltage 21.00 kV
21.00
21.00 kV
1cefd53a-79bd-4ad4-aa9a-5a4ad0191ce2
00X-BE-BE-000031
220
Base Voltage 220 kV
220
220 kV
7891a026ba2c42098556665efd13ba94
00X-BE-BE-000032
225
Base Voltage 225 kV
225
225 kV
63893f24-5b4e-407c-9a1e-4ff71121f33c
00X-BE-BE-000033
380
Base Voltage 380 kV
380
380 kV
35cf638d-9a9d-4ae5-ae90-2f01ef898cb6
00X-BE-BE-000034
400
Base Voltage 400 kV
400
400 kV
65dd04e792584b3b912374e35dec032e
00X-BE-BE-000035
BAY_1
BAY_1
dfa04cac-2b1c-2d4a-b981-ccc03193809f
BAY_1
00X-BE-BE-000036
BE_Breaker_1
false
false
false
999.99
BE_Breaker_1
38dfcc80-600f-44e2-8f71-fb595b4f00ac
Breaker_1
00X-BE-BE-000037
BE_Breaker_10
false
false
false
999.99
BE_Breaker_10
969470b9-e74c-40d2-b3f7-bcfd88400fd1
Breaker_10
00X-BE-BE-000038
BE_Breaker_12
false
false
true
999.99
BE_Breaker_12
96c2b5c8-8e28-4b08-96d2-ca9b09cdbd83
Breaker_12
00X-BE-BE-000039
BE_Breaker_2
false
false
false
999.99
BE_Breaker_2
6b564930-b5e2-49d3-9d06-e1de28d6fd65
Breaker_2
00X-BE-BE-000040
BE_Breaker_3
false
false
false
999.99
BE_Breaker_3
2922c1dd-4113-466e-8cad-002572f3f557
Breaker_3
00X-BE-BE-000041
BE_Breaker_4
false
false
false
999.99
BE_Breaker_4
a603d890-5d9d-42ef-98d0-acf47d121c0e
Breaker_4
00X-BE-BE-000042
BE_Breaker_41
false
false
false
999.99
BE_Breaker_41
8fdd83a5-c284-ec42-be1d-9d55a5fafa65
Breaker_41
00X-BE-BE-000043
BE_Breaker_42
false
false
false
999.99
BE_Breaker_42
604e0f2c-0fdd-2549-95eb-182b62b729c5
Breaker_42
00X-BE-BE-000044
BE_Breaker_5
false
false
false
999.99
BE_Breaker_5
6e86cd52-4594-435e-92ce-6dc673288ab4
Breaker_5
00X-BE-BE-000045
BE_Breaker_51
false
false
false
999.99
BE_Breaker_51
13f6b864-c043-2b4b-894f-c7c8a37ca5a9
Breaker_51
00X-BE-BE-000046
BE_Breaker_52
false
false
false
999.99
BE_Breaker_52
24828a44-2574-7c4a-b6e4-40b57960c8e7
Breaker_52
00X-BE-BE-000047
BE_Breaker_61
false
false
false
999.99
BE_Breaker_61
1079b3fd-619f-7f44-a579-df30a295ce5b
Breaker_61
00X-BE-BE-000048
BE_Breaker_62
false
false
false
999.99
BE_Breaker_62
d63cafb0-6365-d844-b906-e8a5e1fb6a3c
Breaker_62
00X-BE-BE-000049
CIRCB-1230991526
false
false
false
999.99
CIRCB-1230991526
925a3a38-cd26-4f89-8891-c5bc8494e1ae
1230991526
00X-BE-BE-000050
CIRCB-1230991544
false
false
false
999.99
CIRCB-1230991544
484536e9-762a-49a3-9970-d60b9fae03fe
1230991544
00X-BE-BE-000051
CIRCB-1230991718
false
false
false
999.99
CIRCB-1230991718
14d55344-c118-4f54-a430-72f16d12bf7b
1230991718
00X-BE-BE-000052
CIRCB-1230991736
false
false
false
999.99
CIRCB-1230991736
0e8cd279-ad5d-485a-b3a9-093ae8714b72
230991736
00X-BE-BE-000053
CIRCB-1230992276
false
false
false
999.99
CIRCB-1230992276
3b394dab-ab47-4022-98be-8123c6dfe7d4
1230992276
00X-BE-BE-000054
CIRCB-1230992285
false
false
false
999.99
CIRCB-1230992285
ddc148fc-3abd-459d-aec1-396283e0def6
1230992285
00X-BE-BE-000055
CIRCB-1230992399
false
false
false
999.99
CIRCB-1230992399
fd136c65-d001-41a1-adc7-c5430b5c5e72
1230992399
00X-BE-BE-000056
CIRCB-1230992408
false
false
false
999.99
CIRCB-1230992408
0a84038e-1952-4d9d-9909-3b49c364a1ac
1230992408
00X-BE-BE-000057
BUS_BRANCH
1
BUS_BRANCH
14221a68-d5e6-6649-871d-8bb393a72d1c
BUS_BRANCH
00X-BE-BE-000058
BE-Busbar_1
0e+000
BE-Busbar_1
64901aec-5a8a-4bcb-8ca7-a3ddbfcd0e6c
BE-Busbar_1
00X-BE-BE-000059
false
BE-Busbar_2
0e+000
BE-Busbar_2
ef45b632-3028-4afe-bc4c-a4fa323d83fe
BE-Busbar_2
00X-BE-BE-000060
false
BE-Busbar_3
0e+000
BE-Busbar_3
5caf27ed-d2f8-458a-834a-6b3193a982e6
BE-Busbar_3
00X-BE-BE-000061
false
BE-Busbar_4
0e+000
BE-Busbar_4
fd649fe1-bdf5-4062-98ea-bbb66f50402d
BE-Busbar_4
00X-BE-BE-000062
false
BE-Busbar_6
5000.000000
BE-Busbar_6
364c9ca2-0d1d-4363-8f46-e586f8f66a8c
BE-Busbar_6
00X-BE-BE-000063
false
N1230992288
0e+000
N1230992288
63f25be7-7592-4cf1-8401-5772046ef2ae
N1230992288
00X-BE-BE-000064
false
N1230992291
0e+000
N1230992291
c8ce5e08-5ee3-42d9-aa44-5792db252d9f
N1230992291
00X-BE-BE-000065
false
N1230992411
0e+000
N1230992411
8da0ff82-2f23-4231-ac9b-28b9c9141432
N1230992411
00X-BE-BE-000066
false
N1230992414
0e+000
N1230992414
d6986ea6-fadc-4113-806a-a8f95f62c216
N1230992414
00X-BE-BE-000067
false
CMD_1
true
0
0
2015-12-02T16:06:06
SwitchPosition
CMD_1
f2fecbad-7b6d-4643-ba3e-14fbec10806b
CMD_1
00X-BE-BE-000068
BE_CL_1
0.99
0.99
1.0
1.0
BE_CL_1
1324b99a-59ee-0d44-b1f6-15dc0d9d81ff
BE_CL_1
00X-BE-BE-000069
false
BE_CL_GRP_1
BE_CL_GRP_1
0254b245-ca41-134a-ae8c-3d54d8349ba6
BE_CL_GRP_1
00X-BE-BE-000070
BE_CL_SCH_1
2015-12-02T16:06:06
2016-12-02T16:06:05
3153600
BE_CL_SCH_1
a97e3727-b141-ba48-8fd7-7d8843701b8a
BE_CL_SCH_1
00X-BE-BE-000071
BB_Disconector_5
isconector_5
BB_Disconector_5
00X-BE-BE-000072
ec6b1f37-6c5a-ac43-a366-019f5bcce2b1
BB_SC1
BB_SC1
BB_SC1
00X-BE-BE-000073
c0dce815-e4f1-3647-a253-94c187921754
BB_SC_1
BB_SC_1
BB_SC_1
00X-BE-BE-000074
0afe3c6b-c8b5-d946-b05c-e4a8e00a5e6d
BB_SC_2
BB_SC_2
BB_SC_2
00X-BE-BE-000075
ca22a544-e5bb-3a40-91ac-70fb062f39c0
BE-Busbar_1
BE-B_1
BGENT_11; old UCTE code
00X-BE-BE-000076
4836f99b-c6e9-4ee8-a956-b1e3da882d46
BE-Busbar_2
BE-B_2
BBRUS_21; this is UCTE code
00X-BE-BE-000077
ae99bd74-26b1-443a-b1a5-656320283a36
BE-Busbar_3
BE-B_3
BGENT_21; UCTE code
00X-BE-BE-000078
bf851342-832e-4ea2-b2ad-b09729b3af23
BE-Busbar_4
BE-B_4
BGENT_71; This is the old UCTE code from UCTE DEF
00X-BE-BE-000079
0f074167-d8ad-40ed-b0fa-7dc7e9f5f77c
BE-Busbar_5
BE-B_5
BGENT_72; this is old code
00X-BE-BE-000080
f51dce2d-2dc6-4cfe-9486-f9d9a5b0fe33
BE-Busbar_6
BE-B_6
BBRUS151; BGENT_51
00X-BE-BE-000081
1695eb20-9044-4133-a3fd-2147f55f170d
BE-Busbar_EQ
BE-Busbar_EQ
BBRUS_21; this is UCTE code
00X-BE-BE-000082
7531bca1-8648-2e42-af61-810ab0111a60
BE_BB_HVDC1
BE_BB_HVDC1
BE_BB_HVDC1
00X-BE-BE-000107
6ddcc71c-19f8-4171-9814-75f9001b50f1
BE_BUSBAR_10
BE_BUSBAR_10
BE_BUSBAR_10
00X-BE-BE-000083
84c93a56-e0ca-4deb-a2ce-5eeb10682cab
BE_BUSBAR_12
BE_BUSBAR_12
BE_BUSBAR_12
00X-BE-BE-000084
bb6a1e59-1071-4985-b80f-d227cf133067
BE_HVDC_BUS2
BE_HVDC_BUS2
BE_HVDC_BUS2
00X-BE-BE-000085
102ec4fe-8802-420d-81ba-3408d56f6d17
BE_PCC1
BE_PCC1
10T-AT-DE-00017X
10T-AT-DE-00017X
715f08ea-1018-40c9-9fed-aa0dd4c8f8c3
BE_PCC1
BE_PCC1
10T-AT-DE-00017X
10T-AT-DE-00017X
8971465b-6092-4118-a67d-c86d43bba847
BE_PCC2
BE_PCC2
10T-AT-DE-00017X
10T-AT-DE-00017X
57223e58-2106-48ff-92e1-05df1ac984b3
BE_TR4_BUS1
BE_TR4_BUS1
BE_TR4_BUS1
00X-BE-BE-000086
d9a278b0-6bc0-1741-882e-2ba22123e8a3
BE_TR4_BUS2
BE_TR4_BUS2
BE_TR4_BUS2
00X-BE-BE-000087
0392708c-5880-5140-b5c0-6f1153bc333c
BE_TR5_BUS1
BE_TR5_BUS1
BE_TR5_BUS1
00X-BE-BE-000088
ea4745d3-b226-8a4f-ac0d-3fb78920630d
BE_TR5_BUS2
BE_TR5_BUS2
BE_TR5_BUS2
00X-BE-BE-000089
3ba41f2e-78fe-cb4c-8e43-e6c2e553fa08
BE_TR6_BUS1
BE_TR6_BUS1
BE_TR6_BUS1
00X-BE-BE-000090
4d73e700-69ab-8647-9fa8-5232cfca6963
BE_TR6_BUS2
BE_TR6_BUS2
BE_TR6_BUS2
00X-BE-BE-000091
c0201bfc-2c6c-1345-b2da-11320c459d01
BE_TR_BUS1
BE_TR_BUS1
BE_TR_BUS1
00X-BE-BE-000092
d5b267d8-29d8-434b-b3aa-08f8f3435fc0
BE_TR_BUS2
BE_TR_BUS2
BE_TR_BUS2
00X-BE-BE-000093
93cec50e-e92e-4773-b408-e2419dad090d
BE_TR_BUS3
BE_TR_BUS3
BE_TR_BUS3
00X-BE-BE-000094
56ca173b-fd2d-4ef3-bc32-4ae86a318c39
BE_TR_BUS4
BE_TR_BUS4
BE_TR_BUS4
00X-BE-BE-000095
a09067cc-e7b3-4743-8134-f5e42b32e88a
BE_TR_BUS5
BE_TR_BUS5
BE_TR_BUS5
00X-BE-BE-000096
3293fcc7-4962-47df-a7c1-ce150600c388
HCDC1_PCC2
HCDC1_PCC2
10T-AT-DE-00017X
10T-AT-DE-00017X
1fdcc8f7-e491-43db-b8f9-7c1f7b9d7315
HVDC1_BB
HVDC1_BB
HVDC1_BB
00X-BE-BE-000097
c38adab3-5168-4004-a83d-28d890dedd36
N1230816360
N1230816360
N1230816360
00X-BE-BE-000098
d09e0c92-08a5-4d5c-8193-06fa232b3783
N1230991529
N1230991529
N1230991529
00X-BE-BE-000099
21032053-e646-46a7-9a09-6a9a96dbf108
N1230991550
N1230991550
N1230991550
00X-BE-BE-000100
29a37807-af63-402d-ac87-2e248d844793
N1230991724
N1230991724
N1230991724
00X-BE-BE-000101
f33cc626-2c46-46b6-8536-88f30ab532cb
N1230991739
N1230991739
N1230991739
00X-BE-BE-000102
3a849ea6-8dd5-4406-ac11-c89db47ef753
N1230992288
BE-B_3
BGENT_21; UCTE code
00X-BE-BE-000103
18dca121-6c3b-440f-8bf4-8e365b8af551
N1230992291
BE-B_3
BGENT_21; UCTE code
00X-BE-BE-000104
2dde989e-28c3-45f0-aa21-8695843ce894
N1230992411
BE-B_3
BGENT_21; UCTE code
00X-BE-BE-000105
d0aad282-7c05-4990-b0cf-d9168815048e
N1230992414
BE-B_3
BGENT_21; UCTE code
00X-BE-BE-000106
36f63f4c-df3b-4507-baf5-bb4934c09183
CTRL_AREA_1
CTRL_AREA_1
59ca819a-b8f6-4741-8dd4-f688fa26f8ab
CTRL_AREA_1
00X-BE-BE-000108
CTR_AREA_G1
CTR_AREA_G1
b990a941-d921-fc41-8ba8-a87679b299e7
CTR_AREA_G1
00X-BE-BE-000109
Inverter
334.600000
0e+000
167.300000
0e+000
167.300000
0e+000
0e+000
0e+000
0
163.000000
75.000000
2200.000000
110.000000
17.000000
400.000000
2000.000000
Inverter
bdda44e8-7177-4cbc-931d-c879f3723635
Inverter
00X-BE-BE-000110
false
Rectifier
334.600000
0e+000
167.300000
0e+000
167.300000
0e+000
0e+000
0e+000
0
163.000000
75.000000
2200.000000
5.000000
17.000000
400.000000
2000.000000
Rectifier
6a6ee7e4-98d3-4c36-b3f8-6c398f8b6a35
Rectifier
00X-BE-BE-000111
false
90
CL-0
Ratings for element L1230816350 - Limit
1800.000000
723c05d5-f881-4b01-a997-2384b1683c121
00X-BE-BE-000112
90
CL-0
Ratings for element L1230816350 - Limit
1800.000000
936feb98-301f-40d0-a778-cb576b485a661
00X-BE-BE-000113
90
CL-0
Ratings for element L1230816345 - Limit
1800.000000
a930b984-c8c1-4ae9-86bd-382e9f1abc281
00X-BE-BE-000114
90
CL-0
Ratings for element L1230816345 - Limit
1800.000000
200752a1-02ce-485b-be5e-781b254d0c5e1
00X-BE-BE-000115
90
CL-3
Ratings for element BE-Line_7 - Limit
1062.000000
08322f60-4e75-4a00-a4e0-0c55bf5889191
00X-BE-BE-000117
90
CL-5
Ratings for element BE-Line_7 - Limit
1062.000000
2a846bd7-6365-40ea-a7bb-ee1eda61fd7c1
00X-BE-BE-000123
90
CL-3
Ratings for element BE-Line_2 - Limit
1298.700000
3707e6e7-69e5-4f10-bc43-2812519c28421
00X-BE-BE-000125
90
CL-2
Ratings for element BE-Line_2 - Limit
1298.700000
31f7b62d-4707-4067-b1d5-44976db91f001
00X-BE-BE-000128
90
CL-2
Ratings for element BE-Line_3 - Limit
1233.900000
1b18dc2e-d876-4213-b9c2-ddfde01caa5a1
00X-BE-BE-000132
90
CL-2
Ratings for element BE-Line_3 - Limit
1233.900000
3cff44a0-b9a5-4b35-a724-8740d73c07c91
00X-BE-BE-000136
90
CL-4
Ratings for element BE-Line_4 - Limit
1103.400000
382e1966-5b98-4257-a0e5-e0cce107f85d1
00X-BE-BE-000142
90
CL-2
Ratings for element BE-Line_4 - Limit
1103.400000
3ebc30bc-3b24-4ee1-9534-da22e2cd66d11
00X-BE-BE-000144
90
CL-5
Ratings for element BE-Line_5 - Limit
1623.600000
2bb91774-4c1f-4dd6-aeb3-87a3009306c01
00X-BE-BE-000151
90
CL-5
Ratings for element BE-Line_5 - Limit
1623.600000
0068a5c1-9212-4366-8e0e-cf621a92a8b71
00X-BE-BE-000155
90
CL-5
Ratings for element BE-Line_6 - Limit
1062.000000
4dca5f0b-dadf-46c9-aa93-5ff360c120fd1
00X-BE-BE-000159
90
CL-4
Ratings for element BE-Line_6 - Limit
1062.000000
5ba29c54-df69-4e8f-8835-58f7deb762d91
00X-BE-BE-000162
90
CL-5
Ratings for element BE-Line_1 - Limit
1298.700000
6a000ecb-b731-4cc0-9791-980a4d8c28911
00X-BE-BE-000167
90
CL-4
Ratings for element BE-Line_1 - Limit
1350.000000
58c959fd-3675-4ad4-a221-9647b57073dd1
00X-BE-BE-000170
90
CL-0
Ratings for element BE HVDC TR1 - Limit
364.860000
c2cd79f2-b42e-448a-a473-f9fd0f513e9d1
00X-BE-BE-000172
90
CL-0
Ratings for element BE HVDC TR1 - Limit
656.820000
4da5f332-2862-4631-a416-9ea58e6ad7b31
00X-BE-BE-000173
90
CL-0
Ratings for element BE HVDC TR2 - Limit
364.860000
dc664e78-73ac-4d17-9337-bee6da25b7a81
00X-BE-BE-000174
90
CL-0
Ratings for element BE HVDC TR2 - Limit
656.820000
63c9e517-d82b-4366-b6a4-bfb7fefadb141
00X-BE-BE-000175
90
CL-2
Ratings for element BE-TR2_3 - Limit
1177.290000
3503e388-5b7c-4e29-ae10-1f45a2c0c96b1
00X-BE-BE-000176
90
CL-2
Ratings for element BE-TR2_3 - Limit
12371.760000
05b69cbf-0e24-4c98-bd81-9450c751be6f1
00X-BE-BE-000180
90
CL-4
Ratings for element BE-TR2_2 - Limit
1535.220000
30aeec24-ef8f-4fb9-b474-7603449a32fa1
00X-BE-BE-000186
90
CL-3
Ratings for element BE-TR2_2 - Limit
3070.440000
1e91b707-5c8b-4175-861b-b0c2ab2c1a171
00X-BE-BE-000189
90
CL-2
Ratings for element BE-TR2_1 - Limit
844.380000
1c8440dc-e65d-4337-9d3e-7558062228da1
00X-BE-BE-000192
90
CL-3
Ratings for element BE-TR2_1 - Limit
3070.440000
1d5204d8-d24f-49eb-a63e-6c3a632bc15e1
00X-BE-BE-000197
90
CL-4
Ratings for element BE-TR3_1 - Limit
844.380000
55d9cdaf-9b02-448b-9206-f12f3c8d2f641
00X-BE-BE-000202
90
CL-4
Ratings for element BE-TR3_1 - Limit
1535.220000
56a462e6-5117-456b-9d0c-8d62b9a1f14a1
00X-BE-BE-000206
90
CL-2
Ratings for element BE-TR3_1 - Limit
16083.360000
8117eb14-2b1e-4a66-8dfa-54d2fe69c1861
00X-BE-BE-000208
90
CL-0
Ratings for element L1230542419 - Limit
1800.000000
1317ead8-4dc7-4906-86c2-24b56912a0a41
00X-BE-BE-000212
90
CL-2
Ratings for element BE_TR2_HVDC1 - Limit
661.410000
4f7b6db9-1145-4a09-a8f9-942abb0e9cf51
00X-BE-BE-000213
90
CL-0
Ratings for element L1230542424 - Limit
180.000000
542bb003-8acd-4b99-ac3f-7e41051eb5321
00X-BE-BE-000214
90
CL-2
Ratings for element BE_TR2_HVDC2 - Limit
372.510000
7d3a8407-77f9-4b37-8014-f0ac6e8e1e751
00X-BE-BE-000215
90
CL-2
Ratings for element BE_TR2_HVDC1 - Limit
372.510000
a84d68a6-a012-4fec-ac6a-d0e3590f6dcf1
00X-BE-BE-000216
90
CL-2
Ratings for element BE_TR2_HVDC2 - Limit
661.410000
c64c89f1-1ff6-46ba-989a-e83722b213d31
00X-BE-BE-000217
90
CL-0
Ratings for element L1230542419 - Limit
1800.000000
e297170b-a328-44f5-9953-85ec4b259c661
00X-BE-BE-000219
90
CL-5
Ratings for element BE-TR2_1 - Limit
844.380000
20ff7796-0d4b-6543-ac6d-ebf2d835f3ca
00X-BE-BE-000224
90
CL-4
Ratings for element BE-TR2_1 - Limit
3070.440000
6d0f9eba-6ac4-274d-812f-b7786b944dbe
00X-BE-BE-000225
90
CL-2
Ratings for element BE-TR2_1 - Limit
844.380000
05760bc3-7359-2f47-a966-3bdd769ebcf5
00X-BE-BE-000228
90
CL-5
Ratings for element BE-TR2_1 - Limit
3070.440000
06e0ee37-8a03-2f4b-ba65-ca7259701ea4
00X-BE-BE-000235
90
CL-5
Ratings for element BE-TR2_1 - Limit
844.380000
29a9e2db-32d1-7744-b292-f4b71346ce44
00X-BE-BE-000240
90
CL-5
Ratings for element BE-TR2_1 - Limit
3070.440000
6f075b4a-b694-3f41-b4e4-09c7ad3616f5
00X-BE-BE-000243
BE HVDC TR1 - CL-0
CL-0
Ratings for element BE HVDC TR1 - Limit
405.400000
c2cd79f2-b42e-448a-a473-f9fd0f513e9d
00X-BE-BE-000244
BE HVDC TR1 - CL-0
CL-0
Ratings for element BE HVDC TR1 - Limit
729.800000
4da5f332-2862-4631-a416-9ea58e6ad7b3
00X-BE-BE-000245
BE HVDC TR1 - CL-1
CL-1
Ratings for element BE HVDC TR1 - Limit
405.400000
017ffe8f-0bf1-49d5-9af8-fedb6456c1b6
00X-BE-BE-000246
BE HVDC TR1 - CL-1
CL-1
Ratings for element BE HVDC TR1 - Limit
729.800000
dc423087-fba9-4e57-841f-ccd403167b32
00X-BE-BE-000247
BE HVDC TR1 - CL-2
CL-2
Ratings for element BE HVDC TR1 - Limit
405.400000
69f7c8b3-384f-4549-aed6-77f581766559
00X-BE-BE-000248
BE HVDC TR1 - CL-2
CL-2
Ratings for element BE HVDC TR1 - Limit
729.800000
ed85b07a-34a1-4f72-968d-ae3d4a9c91b1
00X-BE-BE-000249
BE HVDC TR2 - CL-0
CL-0
Ratings for element BE HVDC TR2 - Limit
405.400000
dc664e78-73ac-4d17-9337-bee6da25b7a8
00X-BE-BE-000250
BE HVDC TR2 - CL-0
CL-0
Ratings for element BE HVDC TR2 - Limit
729.800000
63c9e517-d82b-4366-b6a4-bfb7fefadb14
00X-BE-BE-000251
BE HVDC TR2 - CL-1
CL-1
Ratings for element BE HVDC TR2 - Limit
405.400000
df78e681-4aa8-44a9-81e7-4004c8200a19
00X-BE-BE-000252
BE HVDC TR2 - CL-1
CL-1
Ratings for element BE HVDC TR2 - Limit
729.800000
e86217e5-8524-4593-a263-c100ee9e343f
00X-BE-BE-000253
BE HVDC TR2 - CL-2
CL-2
Ratings for element BE HVDC TR2 - Limit
405.400000
38e2bd37-a9ff-4bc5-a681-3abdaa1d5457
00X-BE-BE-000254
BE HVDC TR2 - CL-2
CL-2
Ratings for element BE HVDC TR2 - Limit
729.800000
6ad15a43-e661-4739-b3ec-cb7a4b1eb9a3
00X-BE-BE-000255
BE-Line_1 - CL-0
CL-0
Ratings for element BE-Line_1 - Limit
1574.000000
7156a0ea-cf7a-46b0-91c0-a973e1c6feb2
00X-BE-BE-000256
BE-Line_1 - CL-0
CL-0
Ratings for element BE-Line_1 - Limit
1574.000000
ad0fa884-ec20-4908-9986-48ab09ac55cd
00X-BE-BE-000257
BE-Line_1 - CL-1
CL-1
Ratings for element BE-Line_1 - Limit
1705.000000
e9171d11-8877-48ab-a50a-7ede9d4ec4b6
00X-BE-BE-000258
BE-Line_1 - CL-1
CL-1
Ratings for element BE-Line_1 - Limit
1705.000000
19627231-9a8b-45e1-815c-b280a66a59ca
00X-BE-BE-000259
BE-Line_1 - CL-2
CL-2
Ratings for element BE-Line_1 - Limit
1443.000000
f454fa68-0bd5-4e4e-92d6-6108176ad3bf
00X-BE-BE-000260
BE-Line_2 - CL-0
CL-0
Ratings for element BE-Line_2 - Limit
1574.000000
1594f66e-86bd-45da-aa04-3c2bd8e07d76
00X-BE-BE-000268
BE-Line_2 - CL-0
CL-0
Ratings for element BE-Line_2 - Limit
1574.000000
43d42f99-7c35-4907-a6ea-372b41eb8f77
00X-BE-BE-000269
BE-Line_2 - CL-1
CL-1
Ratings for element BE-Line_2 - Limit
1705.000000
6f35cf24-2d5e-4b9a-ac65-943610878a4b
00X-BE-BE-000270
BE-Line_2 - CL-1
CL-1
Ratings for element BE-Line_2 - Limit
1705.000000
3ab4897f-cf5e-418b-8e1c-94f9cde91501
00X-BE-BE-000271
BE-Line_3 - CL-0
CL-0
Ratings for element BE-Line_3 - Limit
1443.000000
e207f382-e138-4a26-a40d-6c01dda96879
00X-BE-BE-000280
BE-Line_3 - CL-0
CL-0
Ratings for element BE-Line_3 - Limit
1443.000000
e537f16f-6107-47a6-a728-797ac246d777
00X-BE-BE-000281
BE-Line_3 - CL-1
CL-1
Ratings for element BE-Line_3 - Limit
1515.000000
ca002966-c9a3-4a17-a12d-1cd32c9d9a7e
00X-BE-BE-000282
BE-Line_3 - CL-1
CL-1
Ratings for element BE-Line_3 - Limit
1515.000000
235676b8-e13c-4400-878f-b0ddc4c9aeae
00X-BE-BE-000283
BE-Line_4 - CL-0
CL-0
Ratings for element BE-Line_4 - Limit
1299.000000
d5a5feb2-8345-487c-a1bc-af3829329391
00X-BE-BE-000292
BE-Line_4 - CL-0
CL-0
Ratings for element BE-Line_4 - Limit
1299.000000
217293df-7f75-4838-8557-d422f7b83c2f
00X-BE-BE-000293
BE-Line_4 - CL-1
CL-1
Ratings for element BE-Line_4 - Limit
1371.000000
e6c72199-8db4-4674-bdd8-d6808afb115e
00X-BE-BE-000294
BE-Line_4 - CL-1
CL-1
Ratings for element BE-Line_4 - Limit
1371.000000
6db95b07-f943-465c-b6ff-844929c07c8b
00X-BE-BE-000295
BE-Line_5 - CL-0
CL-0
Ratings for element BE-Line_5 - Limit
1876.000000
bea68f9e-5348-40dd-ac14-75c41a6a38bd
00X-BE-BE-000304
BE-Line_5 - CL-0
CL-0
Ratings for element BE-Line_5 - Limit
1876.000000
be0d07fc-d20a-430d-82e3-93d48d3f220f
00X-BE-BE-000305
BE-Line_5 - CL-1
CL-1
Ratings for element BE-Line_5 - Limit
1948.000000
3b3fdb5e-dafe-41bb-acfb-eb21be018863
00X-BE-BE-000306
BE-Line_5 - CL-1
CL-1
Ratings for element BE-Line_5 - Limit
1948.000000
a3ecec82-f9e9-4a3c-9cd9-23ae8756ba3c
00X-BE-BE-000307
BE-Line_6 - CL-0
CL-0
Ratings for element BE-Line_6 - Limit
1312.000000
0f8bff64-4cfe-4c94-9471-da94b2efcc4f
00X-BE-BE-000316
BE-Line_6 - CL-0
CL-0
Ratings for element BE-Line_6 - Limit
1312.000000
a634eecf-b900-4808-8b74-d91e36c383a0
00X-BE-BE-000317
BE-Line_6 - CL-1
CL-1
Ratings for element BE-Line_6 - Limit
1443.000000
61870312-e0be-4dd7-8941-22c108b61c30
00X-BE-BE-000318
BE-Line_6 - CL-1
CL-1
Ratings for element BE-Line_6 - Limit
1443.000000
5a4a910c-f57f-456b-b9ca-670ab3676adb
00X-BE-BE-000319
BE-Line_7 - CL-0
CL-0
Ratings for element BE-Line_7 - Limit
1312.000000
6623e566-3111-4050-9b4e-c98d89ba3e69
00X-BE-BE-000328
BE-Line_7 - CL-0
CL-0
Ratings for element BE-Line_7 - Limit
1312.000000
fa8eb432-3107-4562-95fa-7f35d75101b0
00X-BE-BE-000329
BE-Line_7 - CL-1
CL-1
Ratings for element BE-Line_7 - Limit
1443.000000
cce95c87-f08f-47b7-9cdf-f0189a92572f
00X-BE-BE-000330
BE-Line_7 - CL-1
CL-1
Ratings for element BE-Line_7 - Limit
1443.000000
367fe7fa-1b11-4090-af9a-0abc050fda58
00X-BE-BE-000331
BE-TR2_1 - CL-0
CL-0
Ratings for element BE-TR2_1 - Limit
958.200000
aaa63bb1-fa34-41a3-bd92-0637bfce549c
00X-BE-BE-000340
BE-TR2_1 - CL-0
CL-0
Ratings for element BE-TR2_1 - Limit
3611.600000
da1cb116-0730-4a00-b795-8ab0b52ad89f
00X-BE-BE-000341
BE-TR2_1 - CL-0
CL-0
Ratings for element BE-TR2_1 - Limit
958.200000
ff95e92c-9dc8-3143-b85c-03830292e9c6
00X-BE-BE-000342
BE-TR2_1 - CL-0
CL-0
Ratings for element BE-TR2_1 - Limit
3611.600000
ddad129a-1629-b947-8765-516685a86b85
00X-BE-BE-000343
BE-TR2_1 - CL-0
CL-0
Ratings for element BE-TR2_1 - Limit
958.200000
cae89eba-eac8-5b46-acbf-c84ff2f88be0
00X-BE-BE-000344
BE-TR2_1 - CL-0
CL-0
Ratings for element BE-TR2_1 - Limit
3611.600000
f3c6f573-10d2-5444-8e21-cbbecbda45b6
00X-BE-BE-000345
BE-TR2_1 - CL-0
CL-0
Ratings for element BE-TR2_1 - Limit
3611.600000
b9013367-6d85-3f40-8ade-76527e07eb31
00X-BE-BE-000347
BE-TR2_1 - CL-1
CL-1
Ratings for element BE-TR2_1 - Limit
998.200000
acbd4688-6393-4b43-a9f4-27d8c3f8c309
00X-BE-BE-000348
BE-TR2_1 - CL-1
CL-1
Ratings for element BE-TR2_1 - Limit
3811.600000
4af98ccd-29f1-4039-86cd-c23fc2deb3bc
00X-BE-BE-000349
BE-TR2_1 - CL-1
CL-1
Ratings for element BE-TR2_1 - Limit
3811.600000
1a510b8b-4b2b-9842-815b-b858d3d94698
00X-BE-BE-000350
BE-TR2_1 - CL-1
CL-1
Ratings for element BE-TR2_1 - Limit
998.200000
220830b1-c911-2540-834a-f84f6d2914cd
00X-BE-BE-000351
BE-TR2_1 - CL-1
CL-1
Ratings for element BE-TR2_1 - Limit
3811.600000
4aa72957-09ae-4c41-86b4-e3841caa6ff4
00X-BE-BE-000352
BE-TR2_1 - CL-1
CL-1
Ratings for element BE-TR2_1 - Limit
998.200000
d2e8aaa0-bd2c-3b44-9e9b-b7ee30a71103
00X-BE-BE-000353
BE-TR2_1 - CL-1
CL-1
Ratings for element BE-TR2_1 - Limit
3811.600000
67c644c6-b002-cd42-bbb0-b5ccbcad3ad0
00X-BE-BE-000354
BE-TR2_1 - CL-1
CL-1
Ratings for element BE-TR2_1 - Limit
998.200000
62882a04-535c-1041-9904-6b8821b7d7b4
00X-BE-BE-000355
BE-TR2_1 - CL-2
CL-2
Ratings for element BE-TR2_1 - Limit
938.200000
6d16d4a1-c06b-7343-8f40-4ae91d97b1aa
00X-BE-BE-000362
BE-TR2_2 - CL-0
CL-0
Ratings for element BE-TR2_2 - Limit
1805.800000
0d6f26df-9f86-4df0-b00c-bfb23870257f
00X-BE-BE-000388
BE-TR2_2 - CL-0
CL-0
Ratings for element BE-TR2_2 - Limit
3611.600000
7939fc42-08ef-4ce7-9912-97552a4db39a
00X-BE-BE-000389
BE-TR2_2 - CL-1
CL-1
Ratings for element BE-TR2_2 - Limit
1905.800000
5b77485f-20a3-4a19-8d15-e4038c81663f
00X-BE-BE-000390
BE-TR2_2 - CL-1
CL-1
Ratings for element BE-TR2_2 - Limit
3811.600000
84d4dbeb-ef3b-43a1-9a7e-ce5713013498
00X-BE-BE-000391
BE-TR2_3 - CL-0
CL-0
Ratings for element BE-TR2_3 - Limit
1408.100000
a5d3cd27-798c-4910-9729-6fc745346601
00X-BE-BE-000400
BE-TR2_3 - CL-0
CL-0
Ratings for element BE-TR2_3 - Limit
14746.400000
3674d58e-946d-4901-8084-eb21afe1565a
00X-BE-BE-000401
BE-TR2_3 - CL-1
CL-1
Ratings for element BE-TR2_3 - Limit
1508.100000
7059bdb7-fa2d-4061-aea7-a88760835e2f
00X-BE-BE-000402
BE-TR2_3 - CL-1
CL-1
Ratings for element BE-TR2_3 - Limit
15746.400000
a1cfb7e6-ed0d-4369-b555-007826ba82fb
00X-BE-BE-000403
BE-TR3_1 - CL-0
CL-0
Ratings for element BE-TR3_1 - Limit
968.200000
ddcb76e0-13ea-413f-9a8f-553d78782f76
00X-BE-BE-000412
BE-TR3_1 - CL-0
CL-0
Ratings for element BE-TR3_1 - Limit
1805.800000
52d7ccc6-b4a1-48eb-9cfa-f5870b8b7fce
00X-BE-BE-000413
BE-TR3_1 - CL-0
CL-0
Ratings for element BE-TR3_1 - Limit
18870.400000
50448009-0fad-4656-bce4-438fe76e18cf
00X-BE-BE-000414
BE-TR3_1 - CL-1
CL-1
Ratings for element BE-TR3_1 - Limit
998.200000
3e9ed732-dd10-4f10-bc9d-d399e1e75a78
00X-BE-BE-000415
BE-TR3_1 - CL-1
CL-1
Ratings for element BE-TR3_1 - Limit
1905.800000
11763596-6f4b-4cd5-a4a0-be649f368e86
00X-BE-BE-000416
BE-TR3_1 - CL-1
CL-1
Ratings for element BE-TR3_1 - Limit
19870.400000
df2d3155-4436-4542-8d3b-64241c7433be
00X-BE-BE-000417
BE_TR2_HVDC1 - CL-0
CL-0
Ratings for element BE_TR2_HVDC1 - Limit
734.900000
695a62ba-bc23-47e1-b2c1-2c4a588deaaa
00X-BE-BE-000454
BE_TR2_HVDC1 - CL-0
CL-0
Ratings for element BE_TR2_HVDC1 - Limit
413.900000
dd97621c-b564-4c5c-96e4-817b7e9f763f
00X-BE-BE-000455
BE_TR2_HVDC1 - CL-1
CL-1
Ratings for element BE_TR2_HVDC1 - Limit
413.900000
4a47f7f1-3dcd-43f2-8cbd-32556e8078d3
00X-BE-BE-000456
BE_TR2_HVDC1 - CL-1
CL-1
Ratings for element BE_TR2_HVDC1 - Limit
734.900000
904683e1-92c2-4634-ba26-982da30ce40c
00X-BE-BE-000457
BE_TR2_HVDC1 - CL-2
CL-2
Ratings for element BE_TR2_HVDC1 - Limit
734.900000
4f7b6db9-1145-4a09-a8f9-942abb0e9cf5
00X-BE-BE-000458
BE_TR2_HVDC1 - CL-2
CL-2
Ratings for element BE_TR2_HVDC1 - Limit
413.900000
a84d68a6-a012-4fec-ac6a-d0e3590f6dcf
00X-BE-BE-000459
BE_TR2_HVDC2 - CL-0
CL-0
Ratings for element BE_TR2_HVDC2 - Limit
734.900000
0ec5a078-3c99-4057-864a-65c5b1c5e404
00X-BE-BE-000460
BE_TR2_HVDC2 - CL-0
CL-0
Ratings for element BE_TR2_HVDC2 - Limit
413.900000
96dd6a76-1229-4039-9674-db6fc6360533
00X-BE-BE-000461
BE_TR2_HVDC2 - CL-1
CL-1
Ratings for element BE_TR2_HVDC2 - Limit
734.900000
074059a7-9962-453c-bf4b-53911b220669
00X-BE-BE-000462
BE_TR2_HVDC2 - CL-1
CL-1
Ratings for element BE_TR2_HVDC2 - Limit
413.900000
f0bd4e8f-5fec-4b25-a357-522a64f405b1
00X-BE-BE-000463
BE_TR2_HVDC2 - CL-2
CL-2
Ratings for element BE_TR2_HVDC2 - Limit
413.900000
7d3a8407-77f9-4b37-8014-f0ac6e8e1e75
00X-BE-BE-000464
BE_TR2_HVDC2 - CL-2
CL-2
Ratings for element BE_TR2_HVDC2 - Limit
734.900000
c64c89f1-1ff6-46ba-989a-e83722b213d3
00X-BE-BE-000465
L1230542419 - CL-0
CL-0
Ratings for element L1230542419 - Limit
2000.000000
1317ead8-4dc7-4906-86c2-24b56912a0a4
00X-BE-BE-000430
L1230542419 - CL-0
CL-0
Ratings for element L1230542419 - Limit
2000.000000
e297170b-a328-44f5-9953-85ec4b259c66
00X-BE-BE-000431
L1230542419 - CL-1
CL-1
Ratings for element L1230542419 - Limit
2200.000000
122f5b18-be1a-4dc9-abb7-c4ad89c81a50
00X-BE-BE-000432
L1230542419 - CL-1
CL-1
Ratings for element L1230542419 - Limit
2200.000000
57150ea8-4e77-4b3f-b347-7b13226972c1
00X-BE-BE-000433
L1230542419 - CL-2
CL-2
Ratings for element L1230542419 - Limit
2100.000000
06de1962-d8f5-4c06-a723-3a25e71dbcb1
00X-BE-BE-000434
L1230542419 - CL-2
CL-2
Ratings for element L1230542419 - Limit
2100.000000
2406804d-e027-448c-998f-a3dec61735fd
00X-BE-BE-000435
L1230542424 - CL-0
CL-0
Ratings for element L1230542424 - Limit
200.000000
542bb003-8acd-4b99-ac3f-7e41051eb532
00X-BE-BE-000436
L1230542424 - CL-1
CL-1
Ratings for element L1230542424 - Limit
2200.000000
3b7fc8bf-1294-4c3c-b03d-1d24b169546e
00X-BE-BE-000438
L1230542424 - CL-2
CL-2
Ratings for element L1230542424 - Limit
2100.000000
3a661c36-1b83-4246-87d2-52d8a230859f
00X-BE-BE-000440
L1230816345 - CL-0
CL-0
Ratings for element L1230816345 - Limit
2000.000000
a930b984-c8c1-4ae9-86bd-382e9f1abc28
00X-BE-BE-000442
L1230816345 - CL-0
CL-0
Ratings for element L1230816345 - Limit
2000.000000
200752a1-02ce-485b-be5e-781b254d0c5e
00X-BE-BE-000443
L1230816345 - CL-1
CL-1
Ratings for element L1230816345 - Limit
2200.000000
49bc74ba-cc5c-4cd1-834f-038a7b1fd16c
00X-BE-BE-000444
L1230816345 - CL-1
CL-1
Ratings for element L1230816345 - Limit
2200.000000
b7872e34-75ff-44fd-8194-398892d56253
00X-BE-BE-000445
L1230816345 - CL-2
CL-2
Ratings for element L1230816345 - Limit
2100.000000
800459c2-a25e-4caf-977e-4bf0a0ecf5f8
00X-BE-BE-000446
L1230816345 - CL-2
CL-2
Ratings for element L1230816345 - Limit
2100.000000
e6f96403-1342-4eff-8dd0-a8f298ffd1d4
00X-BE-BE-000447
L1230816350 - CL-0
CL-0
Ratings for element L1230816350 - Limit
2000.000000
723c05d5-f881-4b01-a997-2384b1683c12
00X-BE-BE-000448
L1230816350 - CL-0
CL-0
Ratings for element L1230816350 - Limit
2000.000000
936feb98-301f-40d0-a778-cb576b485a66
00X-BE-BE-000449
L1230816350 - CL-1
CL-1
Ratings for element L1230816350 - Limit
2200.000000
7b25b63a-0257-477a-bad9-94783874fec8
00X-BE-BE-000450
L1230816350 - CL-1
CL-1
Ratings for element L1230816350 - Limit
2200.000000
c6bef0b0-400a-4e46-bbd8-a1efb95eaf94
00X-BE-BE-000451
L1230816350 - CL-2
CL-2
Ratings for element L1230816350 - Limit
2100.000000
dce2f14c-5881-4a4e-9c4d-890a25c88bf0
00X-BE-BE-000452
L1230816350 - CL-2
CL-2
Ratings for element L1230816350 - Limit
2100.000000
ec54a5ec-361d-4e57-846f-1521ff399526
00X-BE-BE-000453
-100.000000
-200.000000
200.000000
0e+000
-300.000000
300.000000
100.000000
-200.000000
200.000000
9.99
99.99
99.99
0.99
9.99
9.99
DC_BRK_1
DC_BRK_1
b309f6e1-ba55-534b-9336-38332f828183
DC_BRK_1
00X-BE-BE-000466
false
DC_BB_1
DC_BB_1
7f49502f-c34b-be40-8554-086f41c82144
DC_BB_1
00X-BE-BE-000467
false
DC_CHOP_1
DC_CHOP_1
adc6a737-0988-a542-a833-1e9dc14efaea
DC_CHOP_1
00X-BE-BE-000468
false
InverterUnit
InverterUnit
003260bb-d613-472d-94ee-a24184b22b7d
InverterUnit
00X-BE-BE-000469
RectifierUnit
RectifierUnit
a4e37c92-3db2-4970-b197-1b49120a0b10
ectifierUnit
00X-BE-BE-000470
VSC1Unit
VSC1Unit
8ed4c2fe-e95b-4190-bcd2-7b7de1c432b7
VSC1Unit
00X-BE-BE-000471
VSC_2Unit
VSC_2Unit
e2373e17-8083-46b9-afe9-bf6ce6476545
VSC_2Unit
00X-BE-BE-000472
DC_DSC_1
DC_DSC_1
b889a1fd-a30b-3546-af10-f0ee056f6711
DC_DSC_1
00X-BE-BE-000473
false
DC-1230541231
0e+000
0e+000
DC-1230541231
7b262b4d-3036-498f-a149-130087d18610
1230541231
00X-BE-BE-000474
false
DC-1230541232
0e+000
0e+000
DC-1230541232
dfa333a4-422a-4b29-ad47-922396effe37
1230541232
00X-BE-BE-000475
false
DC-1230541233
0e+000
0e+000
DC-1230541233
09b51dfe-0e32-4fbe-b1dd-7ed98a45a260
1230541233
00X-BE-BE-000476
false
DC-1230541234
0e+000
0e+000
DC-1230541234
74a78aad-6ff8-44c6-af04-7722acad5075
1230541234
00X-BE-BE-000477
false
container of LDC-1230531185
container of LDC-1230531185
fef80c6d-e1e7-47db-b87f-1c18c73e1d33
1230531185
00X-BE-BE-000478
container of LDC-1230816355
container of LDC-1230816355
348015ae-d89a-422f-a5e7-0482f57fc15f
1230816355
00X-BE-BE-000479
LDC-1230531185
2.500000
30.000000
0e+000
1.000000
false
LDC-1230531185
d7693c6d-58bd-49da-bb24-973a63f9faf1
1230531185
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DC_SD_1
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DC_SHUNT_1
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DC_SHUNT_1
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DC_SW_1
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DC_SW_1
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DC-1230541231
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DC-1230541231
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DC-1230541231
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DC-1230541231
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DC-1230541231
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DC-1230541231
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DC-1230541231
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DC-1230541231
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LDC-1230531185
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LDC-1230531185
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00X-BE-BE-000502
LDC-1230531185
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LDC-1230531185
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LDC-1230816355
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LDC-1230816355
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LDC-1230816355
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LDC-1230816355
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00X-BE-BE-000505
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T1
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T1
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T1
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T1
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T1
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T1
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T1
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T1
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T1
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T1
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T1
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T1
1
T1
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T1
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T1
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T1
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T2
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T2
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T2
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T2
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T2
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T2
2
T2
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T2
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T2
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T2
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T2
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T2
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T2
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T2
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All
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BE_DSC_5
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true
BE_DSC_5
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BE_DSC_5
00X-BE-BE-000532
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DIS_1
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DIS_VALUE_1
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98
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DIS_VALUE_1
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DIS_VALUE_1
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BE-Load_1
BE-L_1
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100.0
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BE-Load_2
BE-L_2
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225.0
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ES_1
00X-BE-BE-000538
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EQ_BR_1
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EQ_BR_1
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EQ_BR_1
00X-BE-BE-000539
false
BE-Inj-XCA_AL11
BE-I-XCA_AL1
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100.00
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00X-BE-BE-000540
false
BE-Inj-XKA_MA11
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100.00
100.00
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00X-BE-BE-000541
false
BE-Inj-XWI_GY11
BE-I-XWI_GY1
Eq_Injection
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0e+000
0e+000
0e+000
0e+000
0e+000
0e+000
100.00
100.00
-100.0
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6f014d4c-c1b0-4eed-8d6d-bae3bc87afcf
00X-BE-BE-000542
false
BE-Inj-XZE_ST23
BE-I-XZE_ST2
Eq_Injection
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0e+000
0e+000
0e+000
0e+000
0e+000
0e+000
100.00
100.00
-100.0
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87ea56f3-962a-427a-85d6-13b1f9295174
00X-BE-BE-000543
false
BE-Inj-XZE_ST24
BE-I-XZE_ST2
Eq_Injection
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0e+000
0e+000
0e+000
0e+000
0e+000
0e+000
100.00
100.00
-100.0
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00X-BE-BE-000544
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BOUNDARY
BOUNNDARY
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BOUNDARY
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EQ_NET_1
EQ_NET_1
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EQ_NET_1
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EQ_SHUNT_1
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EQ_SHUNT_1
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EQ_SHUNT_1
00X-BE-BE-000546
false
EX_NET_INJ_1
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99.99
9.99
9.99
9.99
0.99
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0.99
0.99
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99.99
9.99
99.99
9.99
EX_NET_INJ_1
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EX_NET_INJ_1
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FOS_FUEL_1
FOS_FUEL_1
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FOS_FUEL_1
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00X-BE-BE-000550
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99.99
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Gen-ASM_1
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BE
BE
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BE
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GROSS_MW_CRV
GROSS_MW_CRV
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GROSS_MW_CRV
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GROUND_1
GROUND_1
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GROUND_1
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false
GND_DIS_1
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true
9.99
GND_DIS_1
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GND_DIS_1
00X-BE-BE-000555
false
GND_IMP_1
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GND_IMP_1
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GND_IMP_1
00X-BE-BE-000556
false
HYDRO_UNIT_1
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99.99
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0.99
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99.00
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99.99
99.99
99.99
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HYDRO_UNIT_1
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HYDRO_PL_1
HYDRO_PL_1
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HYDRO_PL_1
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HYDRO_PUMP_1
HYDRO_PUMP_1
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HYDRO_PUMP_1
00X-BE-BE-000559
false
JUNCTION_1
JUNCTION_1
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JUNCTION_1
00X-BE-BE-000560
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container of BE-Line_1
container of BE-Line_1
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BE-Line_1
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container of BE-Line_2
container of BE-Line_2
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BE-Line_2
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container of BE-Line_3
container of BE-Line_3
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BE-Line_3
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container of BE-Line_4
container of BE-Line_4
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BE-Line_4
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container of BE-Line_5
container of BE-Line_5
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BE-Line_5
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container of BE-Line_6
container of BE-Line_6
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BE-Line_6
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container of BE-Line_7
container of BE-Line_7
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BE-Line_7
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container of BE_SC_1
container of BE_SC_1
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BE_SC_1
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container of L1230542419
container of L1230542419
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L1230542419
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container of L1230542424
container of L1230542424
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L1230542424
00X-BE-BE-000570
container of L1230816345
container of L1230816345
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L1230816345
00X-BE-BE-000571
container of L1230816350
container of L1230816350
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L1230816350
00X-BE-BE-000572
BE_S1
1
1
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0e+000
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BE_S1
shunt with 4 sections
0.99
false
1
2015-12-02T16:06:06
0.99
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00X-BE-BE-000573
BE_S2
1
1
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7e-006
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BE_S2
another shunt
0.99
false
1
2015-12-02T16:06:06
0.99
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00X-BE-BE-000574
HVDC1
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HVDC1
HVDC1
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false
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2015-12-02T16:06:06
0.99
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HVDC2
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HVDC2
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1
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0.99
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BE_LDAREA_1
BE_LDAREA_1
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BE_LDAREA_1
00X-BE-BE-000577
BE_LB_1
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true
99.99
BE_LB_1
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BE_LB_1
00X-BE-BE-000578
false
L-1230804819
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00X-BE-BE-000579
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ICCP
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ICCP
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MUT_COUP_1
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MUT_COUP_1
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MUT_COUP_1
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BE_NC_1
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BE_NC_1
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BE_NC_1
00X-BE-BE-000582
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BE_NC_LDGROUP1
BE_NC_LDGROUP1
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NC_LDGROUP1
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BE_NC_LDSCH_1
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BE_NC_LDSCH_1
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NC_LDSCH_1
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BE_SHUNT_1
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BE_SHUNT_1
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BE_SHUNT_1
00X-BE-BE-000585
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Gen-BE-G5
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Limits at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE-Line_7 at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE-Line_2 at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE-Line_3 at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE-Line_4 at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE-Line_5 at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE-Line_6 at Port 1
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Limits at Port 1
Limit-Ratings for branch BE-Line_1 at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE HVDC TR1 at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE HVDC TR2 at Port 1
f6dd3ffb-1256-48ae-ac13-9a7d9a9b2fe1
Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE-TR2_3 at Port 1
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Lim at Port1
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Limits at Port 1
Limit-Ratings for branch BE-TR2_2 at Port 1
88aa13e4-d3fe-4c47-9e47-39f8bb805e73
Lim at Port1
00X-BE-BE-000599
Limits at Port 1
Limit-Ratings for branch BE-TR2_1 at Port 1
0b7c4239-3c1b-438e-994d-f2a402ba743c
Lim at Port1
00X-BE-BE-000600
Limits at Port 1
Limit-Ratings for branch BE-TR3_1 at Port 1
b655ab41-8bc0-4bd3-a28c-cf9048e32b4a
Lim at Port1
00X-BE-BE-000601
Limits at Port 1
Limit-Ratings for branch BE_TR2_HVDC2 at Port 1
925eda7d-75a0-4b36-ad12-0d6a68b653a1
Lim at Port1
00X-BE-BE-000603
Limits at Port 1
Limit-Ratings for branch BE_TR2_HVDC1 at Port 1
ad1d7b3b-7282-4510-ad58-4e1f7611e487
Lim at Port1
00X-BE-BE-000604
Limits at Port 1
Limit-Ratings for branch L1230542419 at Port 1
b5f45a95-9a23-4998-bb2c-0b2fe7859215
Lim at Port1
00X-BE-BE-000605
Limits at Port 1
Limit-Ratings for branch BE-TR2_1 at Port 1
b8c037ba-2404-6c4a-8456-a1b9aa389404
Lim at Port1
00X-BE-BE-000606
Limits at Port 1
Limit-Ratings for branch BE-TR2_1 at Port 1
86ea5675-807a-234c-8930-ec61193c5490
Lim at Port1
00X-BE-BE-000607
Limits at Port 1
Limit-Ratings for branch BE-TR2_1 at Port 1
b8c1c533-a8a1-a848-a613-e2abe0d9d67e
Lim at Port1
00X-BE-BE-000608
Limits at Port 1 & 2
Limit-Ratings for branch L1230542424 at Port 1
27f1c422-0845-4fe4-b422-7950cae312ba
For Port 1&2
00X-BE-BE-000602
Limits at Port 2
Limit-Ratings for branch L1230816350 at Port 2
ac88b124-f2f8-4679-ad32-f72e3a486bc3
Lim at Port2
00X-BE-BE-000609
Limits at Port 2
Limit-Ratings for branch L1230816345 at Port 2
851b0c2b-dbf2-45b1-a03f-869e02ab2cd5
Lim at Port2
00X-BE-BE-000610
Limits at Port 2
Limit-Ratings for branch BE-Line_7 at Port 2
00672e1a-599a-44f3-aeaa-5a3c99c29ba1
Lim at Port2
00X-BE-BE-000611
Limits at Port 2
Limit-Ratings for branch BE-Line_2 at Port 2
7168dee1-15a7-4444-839f-feef071e956d
Lim at Port2
00X-BE-BE-000612
Limits at Port 2
Limit-Ratings for branch BE-Line_3 at Port 2
0acd95d7-aff7-41f6-aa8a-863c42f4bc36
Lim at Port2
00X-BE-BE-000613
Limits at Port 2
Limit-Ratings for branch BE-Line_4 at Port 2
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Lim at Port2
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Limits at Port 2
Limit-Ratings for branch BE-Line_5 at Port 2
b639998f-3a5c-496d-96fd-759131b6c307
Lim at Port2
00X-BE-BE-000615
Limits at Port 2
Limit-Ratings for branch BE-Line_6 at Port 2
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Lim at Port2
00X-BE-BE-000616
Limits at Port 2
Limit-Ratings for branch BE-Line_1 at Port 2
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Lim at Port2
00X-BE-BE-000617
Limits at Port 2
Limit-Ratings for branch BE HVDC TR1 at Port 2
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Lim at Port2
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Limits at Port 2
Limit-Ratings for branch BE HVDC TR2 at Port 2
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Lim at Port2
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Limits at Port 2
Limit-Ratings for branch BE-TR2_3 at Port 2
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Lim at Port2
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Limits at Port 2
Limit-Ratings for branch BE-TR2_2 at Port 2
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Lim at Port2
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Limits at Port 2
Limit-Ratings for branch BE-TR2_1 at Port 2
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Lim at Port2
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Limits at Port 2
Limit-Ratings for branch BE-TR3_1 at Port 2
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Lim at Port2
00X-BE-BE-000623
Limits at Port 2
Limit-Ratings for branch BE_TR2_HVDC2 at Port 2
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Lim at Port2
00X-BE-BE-000625
Limits at Port 2
Limit-Ratings for branch BE_TR2_HVDC1 at Port 2
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Lim at Port2
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Limits at Port 2
Limit-Ratings for branch L1230542419 at Port 2
f2487464-9753-4265-afb7-dfa5cdd12c35
Lim at Port2
00X-BE-BE-000627
Limits at Port 2
Limit-Ratings for branch BE-TR2_1 at Port 2
2cdac457-7b01-e344-aef3-ad7667eb5584
Lim at Port2
00X-BE-BE-000628
Limits at Port 2
Limit-Ratings for branch BE-TR2_1 at Port 2
607fc86e-6d46-dc4c-af6b-6824f3bee0fa
Lim at Port2
00X-BE-BE-000629
Limits at Port 2
Limit-Ratings for branch BE-TR2_1 at Port 2
c5a7b1b4-f096-7244-8f14-2962a1bd99e5
Lim at Port2
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Limits at Port 3
Limit-Ratings for branch BE-TR3_1 at Port 3
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Lim at Port2
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Low Voltage Limit
Low Voltage Limit
f1e02491-cea6-7e48-9b3c-926d5df90361
Low KV Limit
00X-BE-BE-000632
LowVoltage
patl
9.99
LowVoltage
b26bc82f-4686-f441-8b00-e1f3a4c9e90b
00X-BE-BE-000633
PATL10
patl10
10.0
PATL10
3e6aa424-8f24-49a5-bbe0-0868441e25ae
00X-BE-BE-000634
PATL20
patl20
20.0
PATL20
9403dcc4-e600-4bd9-96d1-1caecb85cee5
00X-BE-BE-000635
PATLT10
patlt10
10.0
PATLT10
46b5d7be-ac94-4bf2-ad5a-ac9f4e2040dc
00X-BE-BE-000636
PATLT20
patlt20
20.0
PATLT20
ccc21aa9-e333-4c71-a8b1-7e5ab63b3d96
00X-BE-BE-000637
TATL10_1
tatl
10.000000
TATL10_1
6d00cfdb-d400-4acd-b32b-7a48617593e7
00X-BE-BE-000638
TATL10_2
tatl
10.000000
TATL10_2
8419bc3d-8cd7-4a25-9ced-c4df3d2cf504
00X-BE-BE-000639
TATL20_1
tatl
20.000000
TATL20_1
8b859dc8-193a-4a18-912a-1833f45fe926
00X-BE-BE-000640
TATL20_2
tatl
20.000000
TATL20_2
539377b7-53e4-409b-b39a-53ef32add5f9
00X-BE-BE-000641
0.99
0.99
0.99
PET_COIL_1
9.99
225.00
99.99
9.99
9.99
0.99
4.99
PET_COIL_1
ad3aa726-eac8-324c-b95b-1d5d50e76fd7
PET_COIL_1
00X-BE-BE-000642
false
BE_PS_ASYM_1
380.000000
1
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13
10
1.250000
14.518904
14.518904
90.000000
true
BE_PS_ASYM_1
6ebbef67-3061-4236-a6fd-6ccc4595f6c3
BE_PS_ASYM_1
00X-BE-BE-000643
BE_PS_LIN_1
9
1
5
5
true
1.99
9.99
0.99
380.0
BE_PS_LIN_1
c3538b27-3832-5a42-a687-16d520ada5d9
BE_PS_LIN_1
00X-BE-BE-000644
BE_PS_SYM_1
9
1
5
5
true
1.25
380.0
9.99
0.99
BE_PS_SYM_1
752f0335-af17-1348-850f-2b4062f5f4a1
BE_PS_SYM_1
00X-BE-BE-000645
PS_TAB_1
PS_TAB_1
efb74bb3-7791-2548-819b-c8f61d3e455a
PS_TAB_1
00X-BE-BE-000646
9.99
0.99
9.99
9.99
9.99
1
9.99
BE_PS_TAB_1
9
1
5
5
true
400.0
BE_PS_TAB_1
cc4502fe-8cd6-9b47-b612-4ccd30c1e077
BE_PS_TAB_1
00X-BE-BE-000647
BE HVDC TR1
false
0e+000
0e+000
0e+000
0e+000
false
false
BE HVDC TR1
BE HVDC TR1
5e9a25d2-3ccf-4597-b50a-ea8833311144
00X-BE-BE-000648
BE HVDC TR2
false
0e+000
0e+000
0e+000
0e+000
false
false
BE HVDC TR2
BE HVDC TR2
53eca3a5-f203-42e1-aaf0-73769d379c45
00X-BE-BE-000649
BE-TR2_1
false
0e+000
0e+000
0e+000
0e+000
false
false
BE-T_1
T1 that is after maintenance
a708c3bc-465d-4fe7-b6ef-6fa6408a62b0
00X-BE-BE-000650
BE-TR2_2
false
0e+000
0e+000
0e+000
0e+000
false
false
BE-T_2
This is T2 in the center
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00X-BE-BE-000651
BE-TR2_3
false
0e+000
0e+000
0e+000
0e+000
false
false
BE-T_3
This is free description
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00X-BE-BE-000652
BE-TR2_4
false
0e+000
0e+000
0e+000
0e+000
false
false
BE-T_4
T4 that is after maintenance
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00X-BE-BE-000653
BE-TR2_6
false
0e+000
0e+000
0e+000
0e+000
false
false
BE-T_6
T6 that is after maintenance
99f55ee9-2c75-3340-9539-b835ec8c5994
00X-BE-BE-000654
BE-TR3_1
false
0e+000
0e+000
0e+000
0e+000
false
false
BE-T_1
new in 2015
84ed55f4-61f5-4d9d-8755-bba7b877a246
00X-BE-BE-000655
BE_TR2_5
false
0e+000
0e+000
0e+000
0e+000
false
false
BE-T_5
T5 that is after maintenance
cb665311-eab4-ed45-b0f8-9867fc13de9d
00X-BE-BE-000656
BE_TR2_HVDC1
false
0e+000
0e+000
0e+000
0e+000
false
false
BE_TR2_HVDC1
BE_TR2_HVDC1
69a301e8-f6b2-47ad-9f65-52f2eabc9917
00X-BE-BE-000658
HVDC1_TR2_HVDC2
false
0e+000
0e+000
0e+000
0e+000
false
false
C1_TR2_HVDC2
HVDC1_TR2_HVDC2
4ebd554c-1cdb-4f3d-8dd0-dfd4bda8e18c
00X-BE-BE-000657
BE HVDC TR1
0e+000
42.294304
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
158.000000
225.000000
1
0
true
BE HVDC TR1
BE HVDC TR1
c9989583-d2c3-4d52-9f3b-7a98a8211fb6
00X-BE-BE-000659
BE HVDC TR1
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
158.000000
125.000000
2
0
true
BE HVDC TR1
BE HVDC TR1
93328873-3789-4f09-a187-0701c3ea0630
00X-BE-BE-000660
BE HVDC TR2
0e+000
42.294304
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
158.000000
225.000000
1
0
true
BE HVDC TR2
BE HVDC TR2
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00X-BE-BE-000661
BE HVDC TR2
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
158.000000
125.000000
2
0
true
BE HVDC TR2
BE HVDC TR2
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00X-BE-BE-000662
BE-TR2_1
2.707692
14.518904
0.0
0.0
2.720000
14.516604
0.0
0.0
0e+000
0.0
650.000000
380.000000
1
0
false
BE-T_1
BE-TR2_1
49ca3fd4-1b54-4c5b-83fd-4dbd0f9fec9d
00X-BE-BE-000663
BE-TR2_1
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
650.000000
110.000000
2
0
false
BE-T_1
BE-TR2_1
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00X-BE-BE-000664
BE-TR2_2
0.822800
11.138883
0.0
0.0
0.822800
11.138883
0.0
0.0
0e+000
0.0
650.000000
220.000000
1
0
false
BE-T_2
BE-TR2_2
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00X-BE-BE-000665
BE-TR2_2
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
650.000000
110.000000
2
0
false
BE-T_2
BE-TR2_2
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00X-BE-BE-000666
BE-TR2_3
0.104711
5.843419
-0.0000830339
0.0000173295
0.104711
5.843419
0.0
0.0
0e+000
0.0
250.000000
110.343750
1
0
false
BE-T_3
BE-TR2_3
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00X-BE-BE-000667
BE-TR2_3
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
250.000000
10.500000
2
0
false
BE-T_3
BE-TR2_3
35651e25-a77a-46a1-92f4-443d6acce90e
00X-BE-BE-000668
BE-TR2_4
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
650.000000
110.000000
2
0
false
BE-T_4
BE-TR2_4
f04c225b-6aed-1040-8d35-b6a42bf22e30
00X-BE-BE-000669
BE-TR2_4
2.707692
14.518904
0.0
0.0
2.720000
14.516604
0.0
0.0
0e+000
0.0
650.000000
380.000000
1
0
false
BE-T_4
BE-TR2_4
c9796eae-1092-d946-88a3-b1362007caa0
00X-BE-BE-000670
BE-TR2_5
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
650.000000
110.000000
2
0
false
BE-T_5
BE-TR2_5
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00X-BE-BE-000671
BE-TR2_5
2.707692
14.518904
0.0
0.0
2.720000
14.516604
0.0
0.0
0e+000
0.0
650.000000
380.000000
1
0
false
BE-T_5
BE-TR2_5
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00X-BE-BE-000672
BE-TR2_6
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
650.000000
110.000000
2
0
false
BE-T_6
BE-TR2_6
3ee25db5-2305-1d40-a515-01acb2a12e93
00X-BE-BE-000673
BE-TR2_6
2.707692
14.518904
0.0
0.0
2.720000
14.516604
0.0
0.0
0e+000
0.0
650.000000
380.000000
1
0
false
BE-T_4
BE-TR2_6
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00X-BE-BE-000674
BE-TR3_1
0.898462
17.204128
0.0000024375
0.0
0e+000
17.230769
0.0
0.0
0e+000
0.0
650.000000
380.000000
1
0
false
BE-T_1
BE-TR3_1
5f68a129-d5d8-4b71-9743-9ca2572ba26b
00X-BE-BE-000675
BE-TR3_1
0.323908
5.949086
0.0
0.0
0e+000
5.956923
0.0
0.0
0e+000
0.0
650.000000
220.000000
2
0
false
BE-T_1
BE-TR3_1
e1f661c0-971d-4ce5-ad39-0ec427f288ab
00X-BE-BE-000676
BE-TR3_1
0.013332
0.059978
0.0
0.0
0e+000
0.061062
0.0
0.0
0e+000
0.0
650.000000
21.000000
3
0
false
BE-T_1
BE-TR3_1
2e21d1ef-2287-434c-a767-1ca807cf2478
00X-BE-BE-000677
BE_TR2_HVDC1
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
157.700000
123.900000
2
0
true
BE_TR2_HVDC1
BE_TR2_HVDC1
244df133-a500-423b-8a07-bfec41a98920
00X-BE-BE-000678
BE_TR2_HVDC1
0e+000
40.512365
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
157.700000
225.000000
1
0
true
BE_TR2_HVDC1
BE_TR2_HVDC1
9e4b16bb-c8fd-4dd7-84ee-c9bdfdf48664
00X-BE-BE-000679
BE_TR2_HVDC2
0e+000
40.512365
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
157.700000
225.000000
1
0
true
BE_TR2_HVDC2
BE_TR2_HVDC2
3581a7e1-95c0-4778-a108-1a6740abfacb
00X-BE-BE-000680
BE_TR2_HVDC2
0e+000
0e+000
0.0
0.0
0e+000
0e+000
0.0
0.0
0e+000
0.0
157.700000
123.900000
2
0
true
BE_TR2_HVDC2
BE_TR2_HVDC2
922f1973-62d7-4190-9556-39faa8ca39b8
00X-BE-BE-000681
CMD_RL_1
2015-12-02T16:06:06
true
ThreePhaseActivePower
39.99
99.99
CMD_RL_1
d5d18fb4-84eb-9e45-8e84-f9e50344aa99
CMD_RL_1
00X-BE-BE-000682
BE HVDC TR1
225.000000
1
21
11
7
1.000000
true
BE HVDC TR1
BE HVDC TR1
641b8688-b0bc-49c3-9a49-f129851deb4c
00X-BE-BE-000683
BE HVDC TR2
225.000000
1
21
11
7
1.000000
true
BE HVDC TR2
BE HVDC TR2
2aa13bb2-8bcd-4f98-b2ce-c3c444e1d2f0
00X-BE-BE-000684
BE-TR2_2
220.000000
1
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13
10
1.250000
true
BE-T_2
BE-TR2_2
955d9cd0-4a10-4031-b008-60c0dc340a07
00X-BE-BE-000685
BE-TR2_3
10.500000
1
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17
14
0.800000
true
BE-T_3
BE-TR2_3
83cc66dd-8d93-4a2c-8103-f1f5a9cf7e2e
00X-BE-BE-000686
BE-TR3_1
220.000000
1
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17
17
0.625000
true
BE-T_1
BE-TR3_1
fe25f43a-7341-446e-a71a-8ab7119ba806
00X-BE-BE-000687
BE_TR2_HVDC1
225.000000
-10
10
0
0
1.250000
true
BE_TR2_HVDC1
BE_TR2_HVDC1
f11b9b1d-96df-4f20-af1c-a51d4cdb7467
00X-BE-BE-000688
BE_TR2_HVDC2
225.000000
-15
15
0
-2
1.250000
true
BE_TR2_HVDC2
BE_TR2_HVDC2
f6b6428b-d201-4170-89f3-4f630c662b7c
00X-BE-BE-000689
LTC_TAB_1
LTC_TAB_1
5350c2f2-d5f3-8a46-b181-ff619d3cec9d
LTC_TAB_1
00X-BE-BE-000690
9.99
9.99
9.99
5
9.99
0.99
BE-G1
BE-G1
59ff1e53-0e1a-44c0-ada5-7a0b3a660170
BE-G1
00X-BE-BE-000691
1
9.99
0.99
1
9.99
0.99
1
9.99
0.99
1
9.99
0.99
1
225.5
0.99
BE-Anvers
BE-SVC
BE-Anvers
af8df1d5-124e-d64d-8d29-034dc90e7d77
00X-BE-BE-000692
BE-G1
BE-G1
BE-G1
6ba406ce-78cf-4485-9b01-a34e584f1a8d
00X-BE-BE-000693
BE-G2
BE-G2
BE-G2
84bf5be8-eb59-4555-b131-fce4d2d7775d
00X-BE-BE-000694
BE_S1
BE_S1
BE_S1
4d50f86d-0d12-4ca3-9430-56bb05f9eee6
00X-BE-BE-000695
BE_S2
BE_S2
BE_S2
67971e8d-518a-408f-9e59-c7601da9a989
00X-BE-BE-000696
HVDC1
HVDC1
HVDC1
39bfc762-194e-42d9-a8c6-1580a550e601
00X-BE-BE-000697
HVDC2
HVDC2
HVDC2
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00X-BE-BE-000698
REG_SCH_1
2016-12-02T16:06:06
2015-12-02T16:06:06
31526000
REG_SCH_1
c2532221-2ef7-c14d-883b-035db6f8827e
REG_SCH_1
00X-BE-BE-000699
REP_GROUP_1
REP_GROUP_1
de8123e9-3661-a84c-bd6f-3dcd576f4b3c
REP_GROUP_1
00X-BE-BE-000700
All
01-01
12-31
All
ecdff3b4-5ebf-5d47-a7ac-8ec313471f96
All
00X-BE-BE-000701
BE_SC_1
0.99
0.99
true
99.99
9.99
1.99
1.99
BE_SC_1
3619970b-7c3d-bf4f-b499-fb0a99efb362
BE_SC_1
00X-BE-BE-000702
false
SET_PNT_1
ThreePhaseActivePower
true
2015-12-02T16:06:06
120.0
320.0
250.0
156.00
SET_PNT_1
09257ce4-ada8-4f43-a1da-b0366af15caa
SET_PNT_1
00X-BE-BE-000703
Gen-BE-G7
Machine
118.000000
255.000000
200.000000
50.000000
false
200.000000
200.000000
50.000000
0.99
0.99
200.000000
99.99
99.99
99.99
99.99
ea15a4bc-3da5-784b-a417-16be89989995
Gen-BE-G7
00X-BE-BE-000704
SVC_1
0.99
-0.99
0.99
225.0
SVC_1
c68a6a26-7441-a34a-b66b-d370fa2ae873
SVC_1
00X-BE-BE-000705
false
ST_SUPPLY_1
0.99
0.99
99.99
99.99
ST_SUPPLY_1
acfd3fe3-1499-f74a-8c4b-78ed9d14c1c9
ST_SUPPLY_1
00X-BE-BE-000706
false
STR_MEAS_1
ThreePhasePower
STR_MEAS_1
0a9bc3d1-72a7-404f-80d8-d461ed34e4f1
STR_MEAS_1
00X-BE-BE-000707
STR_MEA_V_1
97.00
2015-12-02T16:06:06
For Testing Purpose
STR_MEA_V_1
5e908ccd-fd63-9746-bc39-1ebac7a3fd78
STR_MEA_V_1
00X-BE-BE-000708
ELIA-Anvers
ELIA-Anvers
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ELIA-Anvers
00X-BE-BE-000709
ELIA-Brussels
ELIA-Brussels
c1d5bfc88f8011e08e4d00247eb1f55e
LIA-Brussels
00X-BE-BE-000710
HVDC Zone
HVDC Zone
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HVDC Zone
00X-BE-BE-000711
BE_SUB_LDAREA_1
BE_SUB_LDAREA_1
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SUB_LDAREA_1
00X-BE-BE-000712
Anvers
Anvers
Anvers
87f7002b-056f-4a6a-a872-1744eea757e3
00X-BE-BE-000713
BE_HVDC_Inverter
VDC_Inverter
BE_HVDC_Inverter
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00X-BE-BE-000714
BE_HVDC_Rectifier
DC_Rectifier
BE_HVDC_Rectifier
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00X-BE-BE-000715
HVDC 1
HVDC 1
HVDC 1
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00X-BE-BE-000716
HVDC 2
HVDC 2
HVDC 2
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00X-BE-BE-000717
PP_Brussels
PP_Brussels
PP_Brussels
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00X-BE-BE-000718
BE_SW_1
true
false
999.99
BE_SW_1
deb1fc9b-2bf5-0445-a823-7286a9d1ea45
BE_SW_1
00X-BE-BE-000719
false
SW_SCHED_1
31536000
201612-02T16:06:06
2015-12-02T16:06:06
SW_SCHED_1
c992b87c-691a-eb48-a90b-30f9ce31337c
SW_SCHED_1
00X-BE-BE-000720
BE-G1
BE-G1
Machine
false
50.000000
0e+000
0e+000
300.000000
10.500000
0.850000
0e+000
0e+000
0.130000
0.171000
0e+000
0e+000
0e+000
0.200000
2.000000
0e+000
0e+000
0e+000
0e+000
true
3a3b27be-b18b-4385-b557-6735d733baf0
00X-BE-BE-000721
BE-G2
BE-G2
Machine
false
100.000000
200.000000
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300.000000
21.000000
0.850000
0e+000
0e+000
0.130000
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0e+000
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0.200000
2.000000
0e+000
0e+000
0e+000
0e+000
true
550ebe0d-f2b2-48c1-991f-cebea43a21aa
00X-BE-BE-000722
BE-G3
BE-G3
Machine
false
100.000000
200.000000
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300.000000
21.000000
0.850000
0e+000
0e+000
0.130000
0.170000
0e+000
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0.200000
2.000000
0e+000
0e+000
0e+000
0e+000
true
7dd28bf3-0b93-f540-a620-764aaeb79708
00X-BE-BE-000723
BE-G4
BE-G4
Machine
false
100.000000
200.000000
-200.000000
300.000000
21.000000
0.850000
0e+000
0e+000
0.130000
0.170000
0e+000
0e+000
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0.200000
2.000000
0e+000
0e+000
0e+000
0e+000
true
8454cdd5-2990-b343-9759-5c67e0630d62
00X-BE-BE-000724
BE-G5
BE-G5
Machine
false
100.000000
200.000000
-200.000000
300.000000
21.000000
0.850000
0e+000
0e+000
0.130000
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0.200000
2.000000
0e+000
0e+000
0e+000
0e+000
true
55d4aae2-0d4b-4248-bc90-1193f3499fa0
00X-BE-BE-000725
BE-G6
BE-G6
Machine
false
100.000000
200.000000
-200.000000
300.000000
21.000000
0.850000
0e+000
0e+000
0.130000
0.170000
0e+000
0e+000
0e+000
0.200000
2.000000
0e+000
0e+000
0e+000
0e+000
true
52db5d58-c463-ea47-8259-b8ce5f2fa406
00X-BE-BE-000726
BE-G7
BE-G7
Machine
false
100.000000
200.000000
-200.000000
300.000000
21.000000
0.850000
0e+000
0e+000
0.130000
0.170000
0e+000
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0e+000
0.200000
2.000000
0e+000
0e+000
0e+000
0e+000
true
20f8ce9a-49d2-0543-961b-c59b3999cc24
00X-BE-BE-000727
BE HVDC TR1
BE HVDC TR1
BE HVDC TR1
87e1f736-bde8-499e-abf7-90b310825fb1
00X-BE-BE-000728
BE HVDC TR2
BE HVDC TR2
BE HVDC TR2
631dc0c4-8648-4225-a35d-44c5d3dbb74e
00X-BE-BE-000729
BE-TR2_1
BE-T_1
BE-TR2_1
5fc492ab-fe33-423b-84f1-a47f87552427
00X-BE-BE-000730
BE-TR2_1
BE-T_1
BE-TR2_1
63b20017-8bcd-4b4d-a31d-89dd753650e8
00X-BE-BE-000731
BE-TR2_1
BE-T_1
BE-TR2_1
ae9f40ab-42f3-2143-8282-ae2a09f82160
00X-BE-BE-000732
BE-TR2_1
BE-T_1
BE-TR2_1
99858804-b0aa-9f40-8e81-d8282410392c
00X-BE-BE-000733
BE-TR2_2
BE-T_2
BE-TR2_2
ee42c6c2-39e7-43c2-9bdd-d397c5dc980b
00X-BE-BE-000734
BE-TR2_3
BE-T_3
BE-TR2_3
97110e84-7da6-479c-846c-696fdaa83d56
00X-BE-BE-000735
BE-TR3_1
BE-T_1
BE-TR3_1
38f972bc-b7fd-4e75-8c24-379a86fbb506
00X-BE-BE-000736
BE_TR2_HVDC1
BE_TR2_HVDC1
BE_TR2_HVDC1
40f04fde-8eb3-413b-a594-c4b3eb16b69f
00X-BE-BE-000737
BE_TR2_HVDC2
BE_TR2_HVDC2
BE_TR2_HVDC2
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00X-BE-BE-000738
TAP_SCHED_1
31526000
201612-02T16:06:06
2015-12-02T16:06:06
TAP_SCHED_1
a425852b-184c-4547-b6a6-599a65263f1f
TAP_SCHED_1
00X-BE-BE-000739
BE HVDC TR1 - T1
1
VDC TR1 - T1
BE HVDC TR1 - T1
00X-BE-BE-000740
bd69ce1d-c5c6-4d49-9d4d-0d3ae3691adf
BE HVDC TR1 - T2
2
VDC TR1 - T2
BE HVDC TR1 - T2
00X-BE-BE-000741
204bb7dc-4b03-473c-8761-664d8a08d5e6
BE HVDC TR2 - T1
1
VDC TR2 - T1
BE HVDC TR2 - T1
00X-BE-BE-000742
c6f914d2-15df-4aee-acca-91ea446da16b
BE HVDC TR2 - T2
2
VDC TR2 - T2
BE HVDC TR2 - T2
00X-BE-BE-000743
ca50ea24-48c1-431e-9337-378935f597ff
BE-Busbar_1_Busbar_Section
1
BB
Busbar Section
00X-BE-BE-000744
fa9e0f4d-8a2f-45e1-9e36-3611600d1c94
BE-Busbar_2_Busbar_Section
1
BB
Busbar Section
00X-BE-BE-000745
800ada75-8c8c-4568-aec5-20f799e45f3c
BE-Busbar_3_Busbar_Section
1
BB
Busbar Section
00X-BE-BE-000746
62fc0a4e-00aa-4bf7-b1a0-3a5b2c0b5492
BE-Busbar_4_Busbar_Section
1
BB
Busbar Section
00X-BE-BE-000747
65b8c937-9b25-4b9e-addf-602dbc1337f9
BE-Busbar_6_Busbar_Section
1
BB
Busbar Section
00X-BE-BE-000748
a1b46f53-86f1-497e-bf57-c3b6268bcd6c
BE-G1 - T1
1
BE-G1
BE-G1 - T1
00X-BE-BE-000749
beffa353-7d10-421d-9c08-036b744b1cee
BE-G2 - T1
1
BE-G2
BE-G2 - T1
00X-BE-BE-000750
4bb5407b-b4a5-416c-80ad-1a778ada2b9b
BE-G2 - T1
1
BE-G2
BE-G2 - T1
00X-BE-BE-000751
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BE-G2 - T1
1
BE-G2
BE-G2 - T1
00X-BE-BE-000752
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BE-G2 - T1
1
BE-G2
BE-G2 - T1
00X-BE-BE-000753
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BE-Inj-XCA_AL11 - T1
1
BE-I-XCA_AL1
BE-Inj-XCA_AL11 - T1
00X-BE-BE-000754
53072f42-f77b-47e2-bd9a-e097c910b173
BE-Inj-XKA_MA11 - T1
1
BE-I-XKA_MA1
BE-Inj-XKA_MA11 - T1
00X-BE-BE-000755
c41978db-794b-4bae-953e-60fc519e87dd
BE-Inj-XWI_GY11 - T1
1
BE-I-XWI_GY1
BE-Inj-XWI_GY11 - T1
00X-BE-BE-000756
b9539c41-d114-4280-8a54-8ecec398091e
BE-Inj-XZE_ST23 - T1
1
BE-I-XZE_ST2
BE-Inj-XZE_ST23 - T1
00X-BE-BE-000757
d238885e-d9b6-4edc-8567-6a68c605ed67
BE-Inj-XZE_ST24 - T1
1
BE-I-XZE_ST2
BE-Inj-XZE_ST24 - T1
00X-BE-BE-000758
4a7363a4-0b21-4f65-8bba-33e3a8f6bac3
BE-Line_1 - T1
1
BE-L_1
BE-Line_1 - T1
10T-AT-DE-000061
1ef0715a-d5a9-477b-b6e7-b635529ac140
BE-Line_1 - T2
2
BE-L_1
BE-Line_1 - T2
10T-AT-DE-000061
70d962fb-a492-4c36-8cad-b5c584df53bd
BE-Line_2 - T1
1
BE-L_2
BE-Line_2 - T1
10T-AT-DE-00010A
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BE-Line_2 - T2
2
BE-L_2
BE-Line_2 - T2
10T-AT-DE-00010A
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BE-Line_3 - T1
1
BE-L_3
BE-Line_3 - T1
10T-AT-DE-00008Y
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BE-Line_3 - T2
2
BE-L_3
BE-Line_3 - T2
10T-AT-DE-00008Y
f3b56334-4638-49d3-a6a0-3f417422b8f5
BE-Line_4 - T1
1
BE-L_4
BE-Line_4 - T1
00X-BE-BE-000759
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BE-Line_4 - T2
2
BE-L_4
BE-Line_4 - T2
00X-BE-BE-000760
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BE-Line_5 - T1
1
BE-L_5
BE-Line_5 - T1
10T-AT-DE-00009W
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BE-Line_5 - T2
2
BE-L_5
BE-Line_5 - T2
10T-AT-DE-00009W
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BE-Line_6 - T1
1
BE-L_6
BE-Line_6 - T1
00X-BE-BE-000761
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BE-Line_6 - T2
2
BE-L_6
BE-Line_6 - T2
00X-BE-BE-000762
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BE-Line_7 - T1
1
BE-L_7
BE-Line_7 - T1
10T-AT-DE-000061
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BE-Line_7 - T2
2
BE-L_7
BE-Line_7 - T2
10T-AT-DE-000061
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BE-Load_1 - T1
1
BE-L_1
BE-Load_1 - T1
00X-BE-BE-000763
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BE-Load_2 - T1
1
BE-L_2
BE-Load_2 - T1
00X-BE-BE-000764
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BE-TR2_1 - T1
1
BE-T_1
BE-TR2_1 - T1
00X-BE-BE-000765
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BE-TR2_1 - T2
2
BE-T_1
BE-TR2_1 - T2
00X-BE-BE-000766
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BE-TR2_2 - T1
1
BE-T_2
BE-TR2_2 - T1
00X-BE-BE-000767
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BE-TR2_2 - T2
2
BE-T_2
BE-TR2_2 - T2
00X-BE-BE-000768
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BE-TR2_3 - T1
1
BE-T_3
BE-TR2_3 - T1
00X-BE-BE-000769
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BE-TR2_3 - T2
2
BE-T_3
BE-TR2_3 - T2
00X-BE-BE-000770
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BE-TR2_4 - T1
1
BE-T_4
BE-TR2_4 - T1
00X-BE-BE-000771
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BE-TR2_4 - T2
2
BE-T4_1
BE-TR2_4 - T2
00X-BE-BE-000772
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BE-TR2_5 - T1
1
BE-T5_1
BE-TR2_5 - T1
00X-BE-BE-000773
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BE-TR2_5 - T1
2
BE-T4_1
BE-TR2_5 - T1
00X-BE-BE-000774
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BE-TR2_6 - T1
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BE-T_6
BE-TR2_6 - T1
00X-BE-BE-000775
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BE-TR2_6 - T2
2
BE-T_6
BE-TR2_6 - T2
00X-BE-BE-000776
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BE-TR3_1 - T1
1
BE-T_1
BE-TR3_1 - T1
00X-BE-BE-000777
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BE-TR3_1 - T2
2
BE-T_1
BE-TR3_1 - T2
00X-BE-BE-000778
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BE-TR3_1 - T3
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BE-T_1
BE-TR3_1 - T3
00X-BE-BE-000779
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BE_Breaker_1 - T1
1
BRK_1_T1
BE_Breaker_1 - T1
00X-BE-BE-000780
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BE_Breaker_1 - T2
2
BRK_1_T2
BE_Breaker_1 - T2
00X-BE-BE-000784
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BE_Breaker_10 - T1
1
BRK_10_T1
BE_Breaker_10 - T1
00X-BE-BE-000788
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BE_Breaker_10 - T2
2
BRK_10_T2
BE_Breaker_10 - T2
00X-BE-BE-000789
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BE_Breaker_12 - T1
1
BRK_12_T1
BE_Breaker_12 - T1
00X-BE-BE-000790
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BE_Breaker_12 - T2
2
BRK_12_T2
BE_Breaker_12 - T2
00X-BE-BE-000791
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BE_Breaker_2 - T1
1
BRK_2_T1
BE_Breaker_2 - T1
00X-BE-BE-000792
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PK ! B< < S cimpyorm/res/datasets/MiniGrid_BusBranch/MiniGridTestConfiguration_BC_DL_v3.0.0.xml
2030-01-02T09:00:00
2014-10-22T09:01:25.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
4
http://entsoe.eu/CIM/DiagramLayout/3/1
http://A1.de/Planning/ENTSOE/2
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PK ! ;8%? ? S cimpyorm/res/datasets/MiniGrid_BusBranch/MiniGridTestConfiguration_BC_EQ_v3.0.0.xml
2030-01-02T09:00:00
2015-02-05T12:20:50.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
4
http://entsoe.eu/CIM/EquipmentCore/3/1
http://entsoe.eu/CIM/EquipmentShortCircuit/3/1
http://A1.de/Planning/ENTSOE/2
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PK ! IڰF8 F8 T cimpyorm/res/datasets/MiniGrid_BusBranch/MiniGridTestConfiguration_BC_SSH_v3.0.0.xml
2030-01-02T09:00:00
2014-10-22T09:01:25.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
4
http://entsoe.eu/CIM/SteadyStateHypothesis/1/1
http://A1.de/Planning/ENTSOE/2
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PK ! w% % S cimpyorm/res/datasets/MiniGrid_BusBranch/MiniGridTestConfiguration_BC_SV_v3.0.0.xml
2030-01-02T09:00:00
2014-10-22T09:01:25.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
4
http://entsoe.eu/CIM/StateVariables/4/1
http://A1.de/Planning/ENTSOE/2
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PK ! T5 5 S cimpyorm/res/datasets/MiniGrid_BusBranch/MiniGridTestConfiguration_BC_TP_v3.0.0.xml
2030-01-02T09:00:00
2014-10-22T09:01:25.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
4
http://entsoe.eu/CIM/Topology/4/1
http://A1.de/Planning/ENTSOE/2
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PK !
2030-01-02T09:00:00
2014-11-12T12:01:25.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E as it is". To the fullest extent permitted by law
4
http://entsoe.eu/CIM/DiagramLayout/3/1
http://A1.de/Planning/ENTSOE/2
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1232.08923
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207.310135
1
1592.97583
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1
1200.90369
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1
551.5344
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1
1592.97583
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2
717.792053
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2
1032.86157
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755.887268
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717.792053
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2
506.609436
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1605.823
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1
764.3529
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1
751.6545
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2
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380.8952
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1435.18372
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1
1392.85571
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1
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1
1588.89172
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1282.88293
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2
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1
1559.26208
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1
1304.04688
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2
1371.69165
648.3912
2
551.5344
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1
1358.99329
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1
1538.09814
468.6915
743.188843
223.6465
406.292023
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0
282.715973
610.3355
1282.88293
399.2621
1
1571.96057
399.2621
1
717.792053
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2
1576.04468
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2
1533.86523
399.2621
2
143.125992
207.065231
1
321.635925
207.310135
2
539.282166
552.157959
2
1550.79651
248.150986
1
751.6545
213.47905
1401.32129
648.3912
1316.74536
248.150986
2
751.6545
713.7365
1571.96057
468.6915
0
530.1913
610.725464
1828.66284
468.6915
1308.27979
399.2621
2
1100.5863
791.334167
802.4481
211.394257
1580.42615
248.150986
1
1538.09814
399.2621
785.5169
399.2621
372.4296
611.63446
2
1223.62366
399.2621
2
998.9991
648.3912
2
1533.86523
468.6915
2
1537.94946
648.3912
2
700.86084
611.63446
1
342.799957
207.310135
1
551.5344
308.817352
2
1066.72388
399.2621
2
334.334351
207.310135
1240.55481
399.2621
1
338.567139
207.310135
1
802.4481
399.2621
2
1329.44373
399.2621
2
1354.7605
648.3912
1
806.6809
648.3912
1
1274.41736
170.553452
0
1703.24609
681.462769
2
785.5169
648.3912
1066.72388
399.2621
1075.18945
399.2621
1
551.5344
291.886139
2
355.498352
689.2322
1
551.5344
325.748566
1
1635.45264
468.6915
2
510.6935
223.64
1083.65515
542.2051
2
1223.62366
211.394257
2
143.125992
248.150986
1
785.5169
211.394257
1066.72388
542.2051
1
1066.72388
648.3912
1
764.3529
399.2621
1
1571.96057
248.150986
1
1828.66284
468.6915
1358.99329
542.2051
2
555.618469
611.63
1
1392.85571
648.3912
717.792053
611.63446
551.5344
308.817352
1
1325.21094
399.2621
1342.06213
648.3912
2
772.8185
211.394257
1
1588.89172
203.22612
1375.92456
542.2051
2
1325.21094
248.150986
1007.46454
399.2621
2
551.5344
308.817352
2
802.4481
399.2621
1
1037.09424
648.3912
2
584.2071
501.364227
1
1079.42236
791.334167
1100.5863
648.3912
1614.28857
468.6915
1092.12073
468.6915
1837.12854
468.6915
539.282166
509.829834
2
1695.07788
468.6915
0
1695.07788
248.150986
2
1100.5863
468.6915
2
551.5344
304.584564
1257.48608
399.2621
0
965.229431
789.644531
1384.39014
542.2051
1
372.4296
223.6465
389.3608
611.63446
2
1219.39087
399.2621
2
1070.95667
791.334167
1
1287.11572
399.2621
802.4481
648.3912
1
1274.41736
249.313919
380.8952
611.63446
2
1087.888
468.6915
1
1555.0293
248.150986
2
747.4217
223.6465
1
1062.49109
791.334167
2
539.282166
539.4595
2
1083.65515
791.334167
2
1371.69165
542.2051
1375.92456
648.3912
1811.73169
468.6915
726.2576
223.6465
2
1070.95667
648.3912
1
1555.0293
468.6915
2
1054.02539
542.2051
2
1100.5863
648.3912
1
1559.26208
399.2621
1
1049.79272
789.0177
539.282166
552.157959
1092.12073
648.3912
1
1049.79272
401.578583
2
806.6809
211.394257
2
772.8185
648.3912
2
1571.96057
468.6915
2
1015.93024
648.3912
1538.09814
399.2621
1
1862.52539
468.6915
2
1258.08093
648.3912
2
1219.39087
399.2621
1
708.6545
223.64
2
1571.96057
248.150986
1
539.282166
547.925
1223.62366
211.394257
1
368.196777
611.63446
1
1227.85645
399.2621
1
550.727966
325.748566
2
1028.62878
399.2621
1
1592.97583
619.802734
2
1610.05579
468.6915
751.6545
648.3912
2
1066.72388
791.334167
1049.79272
542.2051
1
1392.85571
542.2051
2
1312.51257
399.2621
2
1054.02539
791.334167
1
798.215332
211.394257
2
1087.888
542.2051
2
978.7294
789.644531
1
1274.41736
213.304657
1426.71814
648.3912
1066.72388
468.6915
2
1358.99329
648.3912
1
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648.3912
1
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648.3912
1
1346.29492
542.2051
1639.68542
468.6915
397.826416
611.63446
1
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611.63446
2
1240.55481
399.2621
2
1626.98694
468.6915
2
1184.56738
648.3912
1
1257.48608
399.2621
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1054.02539
648.3912
2
1066.72388
648.3912
1555.0293
248.150986
1
1576.19336
468.6915
1
1066.72388
399.2621
1
717.792053
223.6465
2
1584.65894
248.150986
1
1104.81909
399.2621
1
1261.71887
399.2621
2
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399.2621
1
785.5169
648.3912
2
1083.65515
468.6915
1
785.5169
399.2621
2
389.3608
611.63446
1
768.5857
399.2621
2
1639.68542
468.6915
1
389.3608
611.63446
1
1015.93024
648.3912
1
722.024841
611.63446
1
1426.71814
648.3912
1
1447.8822
648.3912
1092.12073
399.2621
734.723267
223.6465
1
1542.33093
399.2621
1
1083.65515
542.2051
1075.18945
791.334167
1100.5863
399.2621
2
1684.578
248.150986
1350.52771
648.3912
2
1862.52539
517.7005
2
1083.65515
648.3912
2
700.86084
223.6465
0
1703.24609
738.081543
321.635925
207.310135
1100.5863
468.6915
760.1201
211.394257
1
708.6545
611.63
1580.42615
399.2621
1
1862.52539
468.6915
1567.5791
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998.9991
399.2621
1631.21973
468.6915
2
1555.0293
399.2621
1555.0293
468.6915
1
1592.97583
793.4501
1
802.4481
211.394257
2
1488.542
542.9116
1546.56372
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1571.81189
648.3912
2
755.887268
648.3912
2
1054.02539
399.2621
node-breaker
PK ! s{ { U cimpyorm/res/datasets/MiniGrid_NodeBreaker/MiniGridTestConfiguration_BC_EQ_v3.0.0.xml
2030-01-02T09:00:00
2015-02-05T12:20:50.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
4
http://entsoe.eu/CIM/EquipmentCore/3/1
http://entsoe.eu/CIM/EquipmentOperation/3/1
http://entsoe.eu/CIM/EquipmentShortCircuit/3/1
http://A1.de/Planning/ENTSOE/2
L5_0
1
L5_1
2
L6_0
1
L6_1
2
L4_0
1
L4_1
2
L1_0
1
L1_1
2
L2_0
1
L2_1
2
L3_a_0
1
L3_a_1
2
L3_b_0
1
L3_b_1
2
T5_0
1
T5_1
2
T6_0
1
T6_1
2
T2_0
1
T2_1
2
T1_0
1
T1_1
2
T4_0
1
T4_1
2
T4_2
3
T3_0
1
T3_1
2
T3_2
3
G2_0
1
G1_0
1
G3_0
1
M1_0
1
M2_0
1
ASM-1229750300_0
1
Q1_0
1
Q2_0
1
380kV
380
21kV
21
10kV
10
110kV
110
30kV
30
S2 10kV
S5 10kV
S4 10kV
S3 21kV
S2 110kV
S3 110kV
S1 380kV
S1 30kV
S4 110kV
S1 110kV
Sub1
Sub2
Sub3
Sub4
Sub5
AA
Z1
PATL
45000
TATL
900
TATL
60
Gen-1
G2
false
0
127.5
0
G2
0.9
100
10.5
false
43.6
-43.6
100
0
0.004535
0.16
2
2
7.5
0.005
0.1
0.16
Gen-2
G1
false
0
90
0
G1
0.85
150
21
false
79
-79
100
0
0.00068
0.14
1.8
1.8
0.002
0.1
0.14
Gen-3
G3
false
0
8
0
G3
0.8
10
10.5
false
6
-6
100
0
0.00163
0.1
1.8
1.8
0.018
0.08
0.1
M3
false
0.88
5.828
10
false
97.5
5
1
5
false
0.1
M2a
false
0.89
2.321
10
false
96.8
5.2
2
2
false
0.1
M2b
false
0.89
2.321
10
false
96.8
5.2
2
2
false
0.1
Q1
0
true
38000
800
600
0.15
0.1
3.029
0
-800
-600
0.1
0.1
1
1.1
Q2
0
true
16000
88
66
0.2
0.1
3.34865
0
-88
-66
0
0
0
1.1
Line-7
L5
false
15
0
0
0
0
1.8
3.3
80
5.79
16.5
Ratings
Normal
525
ShortTerm
604
Emergency
735
Line-4
L6
false
1
0
0
0
0
0.082
0.082
80
0.086
0.086
Ratings
Normal
1155
ShortTerm
1328
Emergency
1617
Line-5
L4
false
10
0
0
0
0
0.96
2.2
80
3.88
11
Ratings
Normal
525
ShortTerm
604
Emergency
735
Line-1
L1
false
20
0
0
0
0
2.4
6.4
80
7.8
25.2
Ratings
Normal
525
ShortTerm
604
Emergency
735
Line-6
L2
false
10
0
0
0
0
1.2
3.2
80
3.9
12.6
Ratings
Normal
525
ShortTerm
604
Emergency
735
Line-2
L3_a
false
5
0
0
0
0
0.6
2.6
80
1.95
9.3
Ratings
Normal
525
ShortTerm
604
Emergency
735
Line-3
L3_b
false
5
0
0
0
0
0.6
2.6
80
1.95
9.3
Ratings
Normal
525
ShortTerm
604
Emergency
735
Trafo-1
T5
false
158.14
121.095
36.86
false
false
T5
0
1
false
0
0
0
0
31.5
0
115
0
2.099206
2.099206
50.3372
50.3372
Ratings
Normal
158
ShortTerm
182
Emergency
222
T5
0
2
false
0
0
0
0
31.5
0
10.5
0
0
0
0
0
Ratings
Normal
1732
ShortTerm
1992
Emergency
2425
Trafo-2
T6
false
158.14
121.095
36.86
false
false
T6
0
1
false
0
0
0
0
31.5
0
115
0
2.099206
2.099206
50.3372
50.3372
Ratings
Normal
158
ShortTerm
182
Emergency
222
T6
0
2
true
100
0
0
0
31.5
0
10.5
0
0
0
0
0
Ratings
Normal
1732
ShortTerm
1992
Emergency
2425
Trafo-3
T2
false
115
true
false
T2
0
1
false
0
0
0
0
100
0
120
0
0.72
0.72
17.2649937
17.2649937
Ratings
Normal
481
ShortTerm
553
Emergency
673
T2
2
false
0
0
5
100
0
10.5
0
0
0
0
0
Ratings
Normal
5498
ShortTerm
6323
Emergency
7698
Trafo-4
T1
false
115
true
false
T1
2
false
0
0
5
150
0
21
0
0.0147
0.0147
0.47017
0.446662
Ratings
Normal
4123
ShortTerm
4742
Emergency
5773
T1
25
1
true
13
21
13
1
T1
0
1
true
22
0
0
0
150
0
115
0
0
0
0
0
Ratings
Normal
753
ShortTerm
866
Emergency
1054
T4
false
false
T4
3
false
0
0
5
50
0
30
0
0.0254571438
0.0254571438
1.259741
1.176919
Ratings
Normal
962
ShortTerm
1106
Emergency
1347
T4
0
2
true
0
0
0
0
350
0
120
0
0.05348571429
0.05348571429
-0.001121283618
-0.6881
Ratings
Normal
1683
ShortTerm
1936
Emergency
2357
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30
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481
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PK ! (&X V cimpyorm/res/datasets/MiniGrid_NodeBreaker/MiniGridTestConfiguration_BC_SSH_v3.0.0.xml
2030-01-02T09:00:00
2014-10-22T09:01:25.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
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http://A1.de/Planning/ENTSOE/2
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PK ! dH U cimpyorm/res/datasets/MiniGrid_NodeBreaker/MiniGridTestConfiguration_BC_SV_v3.0.0.xml
2030-01-02T09:00:00
2014-10-22T09:01:25.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
4
http://entsoe.eu/CIM/StateVariables/4/1
http://A1.de/Planning/ENTSOE/2
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PK ! ~}) U cimpyorm/res/datasets/MiniGrid_NodeBreaker/MiniGridTestConfiguration_BC_TP_v3.0.0.xml
2030-01-02T09:00:00
2014-10-22T09:01:25.830
CGMES Conformity Assessment: Mini Grid Base Case Test Configuration. The model is owned by ENTSO-E and is provided by ENTSO-E "as it is". To the fullest extent permitted by law, ENTSO-E shall not be liable for any damages of any kind arising out of the use of the model (including any of its subsequent modifications). ENTSO-E neither warrants, nor represents that the use of the model will not infringe the rights of third parties. Any use of the model shall include a reference to ENTSO-E. ENTSO-E web site is the only official source of information related to the model.
4
http://entsoe.eu/CIM/Topology/4/1
http://A1.de/Planning/ENTSOE/2
Node-1
1
Node-2
8
Node-3
2
Node-9
HG2
Node-10
HG1
Node-11
4
Node-4
H
Node-5
3
Node-6
5
Node-7
6
Node-8
7
PK ! Lȕ S cimpyorm/res/schemata/CIM16/DiagramLayoutProfileRDFSAugmented-v2_4_15-16Feb2016.rdf
DiagramLayoutProfile
This profile has been built on the basis of the IEC 61970-453 document and adjusted to fit the purpose of the ENTSO-E CGMES.
DiagramLayoutVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURI
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/DiagramLayout/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
DiagramLayout
DiagramStyle
The diagram style refer to a style used by the originating system for a diagram. A diagram style describes information such as schematic, geographic, bus-branch etc.
Diagram
A DiagramStyle can be used by many Diagrams.
No
DiagramStyle
A Diagram may have a DiagramStyle.
DiagramStyle
Yes
Diagram
The diagram being exchanged. The coordinate system is a standard Cartesian coordinate system and the orientation attribute defines the orientation.
orientation
Coordinate system orientation of the diagram.
OrientationKind
The orientation of the coordinate system with respect to top, left, and the coordinate number system.
negative
For 2D diagrams, a negative orientation gives the left-hand orientation (favoured by computer graphics displays) with X values increasing from left to right and Y values increasing from top to bottom. This is also known as a left hand orientation.
x1InitialView
X coordinate of the first corner of the initial view.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
x2InitialView
X coordinate of the second corner of the initial view.
y1InitialView
Y coordinate of the first corner of the initial view.
y2InitialView
Y coordinate of the second corner of the initial view.
Diagram
A diagram object is part of a diagram.
Yes
DiagramElements
A diagram is made up of multiple diagram objects.
DiagramElements
No
DiagramObject
An object that defines one or more points in a given space. This object can be associated with anything that specializes IdentifiedObject. For single line diagrams such objects typically include such items as analog values, breakers, disconnectors, power transformers, and transmission lines.
drawingOrder
The drawing order of this element. The higher the number, the later the element is drawn in sequence. This is used to ensure that elements that overlap are rendered in the correct order.
Integer
An integer number. The range is unspecified and not limited.
Primitive
isPolygon
Defines whether or not the diagram objects points define the boundaries of a polygon or the routing of a polyline. If this value is true then a receiving application should consider the first and last points to be connected.
Boolean
A type with the value space "true" and "false".
Primitive
offsetX
The offset in the X direction. This is used for defining the offset from centre for rendering an icon (the default is that a single point specifies the centre of the icon).
The offset is in per-unit with 0 indicating there is no offset from the horizontal centre of the icon. -0.5 indicates it is offset by 50% to the left and 0.5 indicates an offset of 50% to the right.
offsetY
The offset in the Y direction. This is used for defining the offset from centre for rendering an icon (the default is that a single point specifies the centre of the icon).
The offset is in per-unit with 0 indicating there is no offset from the vertical centre of the icon. The offset direction is dependent on the orientation of the diagram, with -0.5 and 0.5 indicating an offset of +/- 50% on the vertical axis.
rotation
Sets the angle of rotation of the diagram object. Zero degrees is pointing to the top of the diagram. Rotation is clockwise.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
IdentifiedObject
The diagram objects that are associated with the domain object.
Yes
DiagramObjects
The domain object to which this diagram object is associated.
DiagramObjects
No
DiagramObjectPoints
A diagram object can have 0 or more points to reflect its layout position, routing (for polylines) or boundary (for polygons).
No
DiagramObject
The diagram object with which the points are associated.
DiagramObject
Yes
VisibilityLayers
A diagram object can be part of multiple visibility layers.
No
VisibleObjects
A visibility layer can contain one or more diagram objects.
VisibleObjects
Yes
DiagramObjectStyle
A diagram object has a style associated that provides a reference for the style used in the originating system.
Yes
StyledObjects
A style can be assigned to multiple diagram objects.
StyledObjects
No
DiagramObjectGluePoint
This is used for grouping diagram object points from different diagram objects that are considered to be glued together in a diagram even if they are not at the exact same coordinates.
DiagramObjectPoints
The 'glue' point to which this point is associated.
No
DiagramObjectGluePoint
A diagram object glue point is associated with 2 or more object points that are considered to be 'glued' together.
DiagramObjectGluePoint
Yes
DiagramObjectPoint
A point in a given space defined by 3 coordinates and associated to a diagram object. The coordinates may be positive or negative as the origin does not have to be in the corner of a diagram.
sequenceNumber
The sequence position of the point, used for defining the order of points for diagram objects acting as a polyline or polygon with more than one point.
xPosition
The X coordinate of this point.
yPosition
The Y coordinate of this point.
zPosition
The Z coordinate of this point.
DiagramObjectStyle
A reference to a style used by the originating system for a diagram object. A diagram object style describes information such as line thickness, shape such as circle or rectangle etc, and color.
TextDiagramObject
A diagram object for placing free-text or text derived from an associated domain object.
text
The text that is displayed by this text diagram object.
VisibilityLayer
Layers are typically used for grouping diagram objects according to themes and scales. Themes are used to display or hide certain information (e.g., lakes, borders), while scales are used for hiding or displaying information depending on the current zoom level (hide text when it is too small to be read, or when it exceeds the screen size). This is also called de-cluttering.
CIM based graphics exchange will support an m:n relationship between diagram objects and layers. It will be the task of the importing system to convert an m:n case into an appropriate 1:n representation if the importing system does not support m:n.
drawingOrder
The drawing order for this layer. The higher the number, the later the layer and the objects within it are rendered.
Core
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
PK ! tb b N cimpyorm/res/schemata/CIM16/DynamicsProfileRDFSAugmented-v2_4_15-16Feb2016.rdf
DynamicsProfile
The CIM dynamic model definitions reflect the most common IEEE or, in the case of wind models, IEC, representations of models as well as models included in some of the transient stability software widely used by utilities.
These dynamic models are intended to ensure interoperability between different vendors’ software products currently in use by electric utility energy companies, utilities, TSOs and RTO/ISOs. It is important to note that each vendor is free to select its own internal implementation of these models. Differences in vendor results, as long as they are within accepted engineering practice, caused by different internal representations, are acceptable.
Notes:
1. Wind models package is defined in accordance with IEC 61400-27-1 version CDV 2013-08-15.
DynamicsVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURI
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/Dynamics/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
Core
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
abstract
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
abstract
ConductingEquipment
The conducting equipment of the terminal. Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
Yes
Terminals
Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
Terminals
No
Equipment
The parts of a power system that are physical devices, electronic or mechanical.
abstract
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
abstract
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
abstract
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
abstract
Terminal
Remote terminal with which this input signal is associated.
Yes
RemoteInputSignal
Input signal coming from this terminal.
RemoteInputSignal
No
Wires
AsynchronousMachine
A rotating machine whose shaft rotates asynchronously with the electrical field. Also known as an induction machine with no external connection to the rotor windings, e.g squirrel-cage induction machine.
abstract
AsynchronousMachine
Asynchronous machine to which this asynchronous machine dynamics model applies.
Yes
AsynchronousMachineDynamics
Asynchronous machine dynamics model used to describe dynamic behavior of this asynchronous machine.
AsynchronousMachineDynamics
No
EnergyConsumer
Generic user of energy - a point of consumption on the power system model.
abstract
Description
EnergyConsumer
Energy consumer to which this dynamics load model applies.
No
LoadDynamics
Load dynamics model used to describe dynamic behavior of this energy consumer.
LoadDynamics
Yes
EnergySource
A generic equivalent for an energy supplier on a transmission or distribution voltage level.
abstract
EnergySource
Energy Source (current source) with which this wind Type 3 or 4 dynamics model is asoociated.
Yes
WindTurbineType3or4Dynamics
Wind generator Type 3 or 4 dynamics model associated with this energy source.
WindTurbineType3or4Dynamics
No
RegulatingCondEq
A type of conducting equipment that can regulate a quantity (i.e. voltage or flow) at a specific point in the network.
abstract
RotatingMachine
A rotating machine which may be used as a generator or motor.
abstract
SynchronousMachine
An electromechanical device that operates with shaft rotating synchronously with the network. It is a single machine operating either as a generator or synchronous condenser or pump.
abstract
SynchronousMachine
Synchronous machine to which synchronous machine dynamics model applies.
Yes
SynchronousMachineDynamics
Synchronous machine dynamics model used to describe dynamic behavior of this synchronous machine.
SynchronousMachineDynamics
No
StandardInterconnections
This section describes the standard interconnections for various types of equipment. These interconnections are understood by the application programs and can be identified based on the presence of one of the key classes with a relationship to the static power flow model: SynchronousMachineDynamics, AsynchronousMachineDynamics, EnergyConsumerDynamics or WindTurbineType3or4Dynamics.
The relationships between classes expressed in the interconnection diagrams are intended to support dynamic behaviour described by either standard models or user-defined models.
In the interconnection diagrams, boxes which are black in colour represent function blocks whose functionality can be provided by one of many standard models or by a used-defined model. Blue boxes represent specific standard models. A dashed box means that the function block or specific standard model is optional.
RemoteInputSignal
Supports connection to a terminal associated with a remote bus from which an input signal of a specific type is coming.
remoteSignalType
Type of input signal.
RemoteSignalKind
Type of input signal coming from remote bus.
remoteBusVoltageFrequency
Input is voltage frequency from remote terminal bus.
remoteBusVoltageFrequencyDeviation
Input is voltage frequency deviation from remote terminal bus.
remoteBusFrequency
Input is frequency from remote terminal bus.
remoteBusFrequencyDeviation
Input is frequency deviation from remote terminal bus.
remoteBusVoltageAmplitude
Input is voltage amplitude from remote terminal bus.
remoteBusVoltage
Input is voltage from remote terminal bus.
remoteBranchCurrentAmplitude
Input is branch current amplitude from remote terminal bus.
remoteBusVoltageAmplitudeDerivative
Input is branch current amplitude derivative from remote terminal bus.
remotePuBusVoltageDerivative
Input is PU voltage derivative from remote terminal bus.
RemoteInputSignal
Remote input signal used by this Power Factor or VAr controller Type I model.
No
PFVArControllerType1Dynamics
Power Factor or VAr controller Type I model using this remote input signal.
PFVArControllerType1Dynamics
Yes
RemoteInputSignal
Remote input signal used by this underexcitation limiter model.
No
UnderexcitationLimiterDynamics
Underexcitation limiter model using this remote input signal.
UnderexcitationLimiterDynamics
Yes
RemoteInputSignal
Remote input signal used by this wind generator Type 1 or Type 2 model.
Yes
WindTurbineType1or2Dynamics
Wind generator Type 1 or Type 2 model using this remote input signal.
WindTurbineType1or2Dynamics
No
RemoteInputSignal
Remote input signal used by this voltage compensator model.
No
VoltageCompensatorDynamics
Voltage compensator model using this remote input signal.
VoltageCompensatorDynamics
Yes
RemoteInputSignal
Remote input signal used by this power system stabilizer model.
No
PowerSystemStabilizerDynamics
Power system stabilizer model using this remote input signal.
PowerSystemStabilizerDynamics
Yes
RemoteInputSignal
Remote input signal used by this discontinuous excitation control system model.
No
DiscontinuousExcitationControlDynamics
Discontinuous excitation control model using this remote input signal.
DiscontinuousExcitationControlDynamics
Yes
WindTurbineType3or4Dynamics
Remote input signal used by these wind turbine Type 3 or 4 models.
No
RemoteInputSignal
Wind turbine Type 3 or 4 models using this remote input signal.
RemoteInputSignal
Yes
WindPlantDynamics
The remote signal with which this power plant is associated.
No
RemoteInputSignal
The wind plant using the remote signal.
RemoteInputSignal
Yes
StandardModels
This section contains standard dynamic model specifications grouped into packages by standard function block (type of equipment being modelled).
In the CIM, standard dynamic models are expressed by means of a class named with the standard model name and attributes reflecting each of the parameters necessary to describe the behaviour of an instance of the standard model.
DynamicsFunctionBlock
Abstract parent class for all Dynamics function blocks.
abstract
enabled
Function block used indicator.
true = use of function block is enabled
false = use of function block is disabled.
Boolean
A type with the value space "true" and "false".
Primitive
RotatingMachineDynamics
Abstract parent class for all synchronous and asynchronous machine standard models.
abstract
damping
Damping torque coefficient (D). A proportionality constant that, when multiplied by the angular velocity of the rotor poles with respect to the magnetic field (frequency), results in the damping torque. This value is often zero when the sources of damping torques (generator damper windings, load damping effects, etc.) are modelled in detail. Typical Value = 0.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
inertia
Inertia constant of generator or motor and mechanical load (H) (>0). This is the specification for the stored energy in the rotating mass when operating at rated speed. For a generator, this includes the generator plus all other elements (turbine, exciter) on the same shaft and has units of MW*sec. For a motor, it includes the motor plus its mechanical load. Conventional units are per unit on the generator MVA base, usually expressed as MW*second/MVA or just second. This value is used in the accelerating power reference frame for operator training simulator solutions. Typical Value = 3.
Seconds
Time, in seconds.
CIMDatatype
value
Time, in seconds
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
saturationFactor
Saturation factor at rated terminal voltage (S1) (> or =0). Not used by simplified model. Defined by defined by S(E1) in the SynchronousMachineSaturationParameters diagram. Typical Value = 0.02.
saturationFactor120
Saturation factor at 120% of rated terminal voltage (S12) (> or =S1). Not used by the simplified model, defined by S(E2) in the SynchronousMachineSaturationParameters diagram. Typical Value = 0.12.
statorLeakageReactance
Stator leakage reactance (Xl) (> or =0). Typical Value = 0.15.
PU
Per Unit - a positive or negative value referred to a defined base. Values typically range from -10 to +10.
CIMDatatype
value
unit
multiplier
statorResistance
Stator (armature) resistance (Rs) (> or =0). Typical Value = 0.005.
UserDefinedModels
This package contains user-defined dynamic model classes to support the exchange of both proprietary and explicitly defined models.
Proprietary models have behavior which, while not defined by a standard model class, is mutually understood by the sending and receiving applications based on the name passed in the .name attribute of the xxxUserDefined class. Parameters are passed as general attributes using as many instances of the ProprietaryParameterDynamics class as there are parameters.
Explicitly defined models describe dynamic behavior in detail in terms of control blocks and their input and output signals. NOTE: The classes to support explicitly defined modeling are not currently defined - it is future work. They are described here to document the current thinking on where they would be added.
WindPlantUserDefined
Wind plant function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
No
WindPlantUserDefined
Proprietary user-defined model with which this parameter is associated.
WindPlantUserDefined
Yes
WindType1or2UserDefined
Wind Type 1 or Type 2 function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
No
WindType1or2UserDefined
Proprietary user-defined model with which this parameter is associated.
WindType1or2UserDefined
Yes
WindType3or4UserDefined
Wind Type 3 or Type 4 function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
No
WindType3or4UserDefined
Proprietary user-defined model with which this parameter is associated.
WindType3or4UserDefined
Yes
SynchronousMachineUserDefined
Synchronous machine whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
SynchronousMachineUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
AsynchronousMachineUserDefined
Asynchronous machine whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
AsynchronousMachineUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
TurbineGovernorUserDefined
Turbine-governor function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
TurbineGovernorUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
TurbineLoadControllerUserDefined
Turbine load controller function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
TurbineLoadControllerUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
MechanicalLoadUserDefined
Mechanical load function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
MechanicalLoadUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
ExcitationSystemUserDefined
Excitation system function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
ExcitationSystemUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
OverexcitationLimiterUserDefined
Overexcitation limiter system function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
OverexcitationLimiterUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
UnderexcitationLimiterUserDefined
Underexcitation limiter function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
UnderexcitationLimiterUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
PowerSystemStabilizerUserDefined
Power system stabilizer function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
PowerSystemStabilizerUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
DiscontinuousExcitationControlUserDefined
Discontinuous excitation control function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
DiscontinuousExcitationControlUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
PFVArControllerType1UserDefined
Power Factor or VAr controller Type I function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
PFVArControllerType1UserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
VoltageAdjusterUserDefined
Voltage adjuster function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
VoltageAdjusterUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
PFVArControllerType2UserDefined
Power Factor or VAr controller Type II function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
PFVArControllerType2UserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
VoltageCompensatorUserDefined
Voltage compensator function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
VoltageCompensatorUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
LoadUserDefined
Load whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
LoadUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
ProprietaryParameterDynamics
Supports definition of one or more parameters of several different datatypes for use by proprietary user-defined models. NOTE: This class does not inherit from IdentifiedObject since it is not intended that a single instance of it be referenced by more than one proprietary user-defined model instance.
parameterNumber
Sequence number of the parameter among the set of parameters associated with the related proprietary user-defined model.
Integer
An integer number. The range is unspecified and not limited.
Primitive
booleanParameterValue
Used for boolean parameter value. If this attribute is populated, integerParameterValue and floatParameterValue will not be.
integerParameterValue
Used for integer parameter value. If this attribute is populated, booleanParameterValue and floatParameterValue will not be.
floatParameterValue
Used for floating point parameter value. If this attribute is populated, booleanParameterValue and integerParameterValue will not be.
SynchronousMachineDynamics
For conventional power generating units (e.g., thermal, hydro, combustion turbine), a synchronous machine model represents the electrical characteristics of the generator and the mechanical characteristics of the turbine-generator rotational inertia. Large industrial motors or groups of similar motors may be represented by individual motor models which are represented as generators with negative active power in the static (power flow) data.
The interconnection with the electrical network equations may differ among simulation tools. The tool only needs to know the synchronous machine to establish the correct interconnection. The interconnection with motor’s equipment could also differ due to input and output signals required by standard models.
SynchronousMachineSimplified
The simplified model represents a synchronous generator as a constant internal voltage behind an impedance (Rs + jXp) as shown in the Simplified diagram.
Since internal voltage is held constant, there is no Efd input and any excitation system model will be ignored. There is also no Ifd output.
This model should not be used for representing a real generator except, perhaps, small generators whose response is insignificant.
The parameters used for the Simplified model include:
- RotatingMachineDynamics.damping (D)
- RotatingMachineDynamics.inertia (H)
- RotatingMachineDynamics.statorLeakageReactance (used to exchange jXp for SynchronousMachineSimplified)
- RotatingMachineDynamics.statorResistance (Rs).
SynchronousMachineDynamics
Synchronous machine whose behaviour is described by reference to a standard model expressed in one of the following forms:
- simplified (or classical), where a group of generators or motors is not modelled in detail
- detailed, in equivalent circuit form
- detailed, in time constant reactance form
or by definition of a user-defined model.
Note: It is a common practice to represent small generators by a negative load rather than by a dynamic generator model when performing dynamics simulations. In this case a SynchronousMachine in the static model is not represented by anything in the dynamics model, instead it is treated as ordinary load.
Parameter Notes:
- Synchronous machine parameters such as Xl, Xd, Xp etc. are actually used as inductances (L) in the models, but are commonly referred to as reactances since, at nominal frequency, the per unit values are the same. However, some references use the symbol L instead of X.
abstract
SynchronousMachineDynamics
Turbine-governor model associated with this synchronous machine model.
Yes
TurbineGovernorDynamics
Synchronous machine model with which this turbine-governor model is associated.
TurbineGovernorDynamics
No
SynchronousMachineDynamics
Synchronous machine model with which this excitation system model is associated.
Yes
ExcitationSystemDynamics
Excitation system model associated with this synchronous machine model.
ExcitationSystemDynamics
No
SynchronousMachineDynamics
Synchronous machine model with which this mechanical load model is associated.
Yes
MechanicalLoadDynamics
Mechanical load model associated with this synchronous machine model.
MechanicalLoadDynamics
No
SynchronousMachineDynamics
Standard synchronous machine out of which current flow is being compensated for.
Yes
GenICompensationForGenJ
Compensation of voltage compensator's generator for current flow out of this generator.
GenICompensationForGenJ
No
SynchronousMachineDetailed
All synchronous machine detailed types use a subset of the same data parameters and input/output variables.
The several variations differ in the following ways:
- The number of equivalent windings that are included
- The way in which saturation is incorporated into the model.
- Whether or not “subtransient saliency” (X''q not = X''d) is represented.
Note: It is not necessary for each simulation tool to have separate models for each of the model types. The same model can often be used for several types by alternative logic within the model. Also, differences in saturation representation may not result in significant model performance differences so model substitutions are often acceptable.
abstract
saturationFactorQAxis
Q-axis saturation factor at rated terminal voltage (S1q) (>= 0). Typical Value = 0.02.
saturationFactor120QAxis
Q-axis saturation factor at 120% of rated terminal voltage (S12q) (>=S1q). Typical Value = 0.12.
efdBaseRatio
Ratio of Efd bases of exciter and generator models. Typical Value = 1.
ifdBaseType
Excitation base system mode. Typical Value = ifag.
IfdBaseKind
Excitation base system mode.
ifag
Air gap line mode. ifdBaseValue is computed, not defined by the user, in this mode.
ifnl
No load system with saturation mode. ifdBaseValue is computed, not defined by the user, in this mode.
iffl
Full load system mode. ifdBaseValue is computed, not defined by the user, in this mode.
other
Free mode. ifdBaseValue is defined by the user in this mode.
ifdBaseValue
Ifd base current if .ifdBaseType = other.
Not needed if .ifdBaseType not = other.
Unit = A. Typical Value = 0.
CurrentFlow
Electrical current with sign convention: positive flow is out of the conducting equipment into the connectivity node. Can be both AC and DC.
CIMDatatype
value
unit
multiplier
SynchronousMachineTimeConstantReactance
Synchronous machine detailed modelling types are defined by the combination of the attributes SynchronousMachineTimeConstantReactance.modelType and SynchronousMachineTimeConstantReactance.rotorType.
Parameter notes:
- The “p” in the time-related attribute names is a substitution for a “prime” in the usual parameter notation, e.g. tpdo refers to T'do.
The parameters used for models expressed in time constant reactance form include:
- RotatingMachine.ratedS (MVAbase)
- RotatingMachineDynamics.damping (D)
- RotatingMachineDynamics.inertia (H)
- RotatingMachineDynamics.saturationFactor (S1)
- RotatingMachineDynamics.saturationFactor120 (S12)
- RotatingMachineDynamics.statorLeakageReactance (Xl)
- RotatingMachineDynamics.statorResistance (Rs)
- SynchronousMachineTimeConstantReactance.ks (Ks)
- SynchronousMachineDetailed.saturationFactorQAxis (S1q)
- SynchronousMachineDetailed.saturationFactor120QAxis (S12q)
- SynchronousMachineDetailed.efdBaseRatio
- SynchronousMachineDetailed.ifdBaseType
- SynchronousMachineDetailed.ifdBaseValue, if present
- .xDirectSync (Xd)
- .xDirectTrans (X'd)
- .xDirectSubtrans (X''d)
- .xQuadSync (Xq)
- .xQuadTrans (X'q)
- .xQuadSubtrans (X''q)
- .tpdo (T'do)
- .tppdo (T''do)
- .tpqo (T'qo)
- .tppqo (T''qo)
- .tc.
rotorType
Type of rotor on physical machine.
RotorKind
Type of rotor on physical machine.
roundRotor
Round rotor type of synchronous machine.
salientPole
Salient pole type of synchronous machine.
modelType
Type of synchronous machine model used in Dynamic simulation applications.
SynchronousMachineModelKind
Type of synchronous machine model used in Dynamic simulation applications.
subtransient
Subtransient synchronous machine model.
subtransientTypeF
WECC Type F variant of subtransient synchronous machine model.
subtransientTypeJ
WECC Type J variant of subtransient synchronous machine model.
subtransientSimplified
Simplified version of subtransient synchronous machine model where magnetic coupling between the direct and quadrature axes is ignored.
subtransientSimplifiedDirectAxis
Simplified version of a subtransient synchronous machine model with no damper circuit on d-axis.
ks
Saturation loading correction factor (Ks) (>= 0). Used only by Type J model. Typical Value = 0.
xDirectSync
Direct-axis synchronous reactance (Xd) (>= X'd).
The quotient of a sustained value of that AC component of armature voltage that is produced by the total direct-axis flux due to direct-axis armature current and the value of the AC component of this current, the machine running at rated speed. Typical Value = 1.8.
xDirectTrans
Direct-axis transient reactance (unsaturated) (X'd) (> =X''d). Typical Value = 0.5.
xDirectSubtrans
Direct-axis subtransient reactance (unsaturated) (X''d) (> Xl). Typical Value = 0.2.
xQuadSync
Quadrature-axis synchronous reactance (Xq) (> =X'q).
The ratio of the component of reactive armature voltage, due to the quadrature-axis component of armature current, to this component of current, under steady state conditions and at rated frequency. Typical Value = 1.6.
xQuadTrans
Quadrature-axis transient reactance (X'q) (> =X''q). Typical Value = 0.3.
xQuadSubtrans
Quadrature-axis subtransient reactance (X''q) (> Xl). Typical Value = 0.2.
tpdo
Direct-axis transient rotor time constant (T'do) (> T''do). Typical Value = 5.
tppdo
Direct-axis subtransient rotor time constant (T''do) (> 0). Typical Value = 0.03.
tpqo
Quadrature-axis transient rotor time constant (T'qo) (> T''qo). Typical Value = 0.5.
tppqo
Quadrature-axis subtransient rotor time constant (T''qo) (> 0). Typical Value = 0.03.
tc
Damping time constant for “Canay” reactance. Typical Value = 0.
SynchronousMachineEquivalentCircuit
The electrical equations for all variations of the synchronous models are based on the SynchronousEquivalentCircuit diagram for the direct and quadrature axes.
Equations for conversion between Equivalent Circuit and Time Constant Reactance forms:
Xd = Xad + Xl
X’d = Xl + Xad * Xfd / (Xad + Xfd)
X”d = Xl + Xad * Xfd * X1d / (Xad * Xfd + Xad * X1d + Xfd * X1d)
Xq = Xaq + Xl
X’q = Xl + Xaq * X1q / (Xaq+ X1q)
X”q = Xl + Xaq * X1q* X2q / (Xaq * X1q + Xaq * X2q + X1q * X2q)
T’do = (Xad + Xfd) / (omega0 * Rfd)
T”do = (Xad * Xfd + Xad * X1d + Xfd * X1d) / (omega0 * R1d * (Xad + Xfd)
T’qo = (Xaq + X1q) / (omega0 * R1q)
T”qo = (Xaq * X1q + Xaq * X2q + X1q * X2q)/ (omega0 * R2q * (Xaq + X1q)
Same equations using CIM attributes from SynchronousMachineTimeConstantReactance class on left of = sign and SynchronousMachineEquivalentCircuit class on right (except as noted):
xDirectSync = xad + RotatingMachineDynamics.statorLeakageReactance
xDirectTrans = RotatingMachineDynamics.statorLeakageReactance + xad * xfd / (xad + xfd)
xDirectSubtrans = RotatingMachineDynamics.statorLeakageReactance + xad * xfd * x1d / (xad * xfd + xad * x1d + xfd * x1d)
xQuadSync = xaq + RotatingMachineDynamics.statorLeakageReactance
xQuadTrans = RotatingMachineDynamics.statorLeakageReactance + xaq * x1q / (xaq+ x1q)
xQuadSubtrans = RotatingMachineDynamics.statorLeakageReactance + xaq * x1q* x2q / (xaq * x1q + xaq * x2q + x1q * x2q)
tpdo = (xad + xfd) / (2*pi*nominal frequency * rfd)
tppdo = (xad * xfd + xad * x1d + xfd * x1d) / (2*pi*nominal frequency * r1d * (xad + xfd)
tpqo = (xaq + x1q) / (2*pi*nominal frequency * r1q)
tppqo = (xaq * x1q + xaq * x2q + x1q * x2q)/ (2*pi*nominal frequency * r2q * (xaq + x1q).
Are only valid for a simplified model where "Canay" reactance is zero.
xad
D-axis mutual reactance.
rfd
Field winding resistance.
xfd
Field winding leakage reactance.
r1d
D-axis damper 1 winding resistance.
x1d
D-axis damper 1 winding leakage reactance.
xf1d
Differential mutual (“Canay”) reactance.
xaq
Q-axis mutual reactance.
r1q
Q-axis damper 1 winding resistance.
x1q
Q-axis damper 1 winding leakage reactance.
r2q
Q-axis damper 2 winding resistance.
x2q
Q-axis damper 2 winding leakage reactance.
AsynchronousMachineDynamics
An asynchronous machine model represents a (induction) generator or motor with no external connection to the rotor windings, e.g., squirrel-cage induction machine.
The interconnection with the electrical network equations may differ among simulation tools. The program only needs to know the terminal to which this asynchronous machine is connected in order to establish the correct interconnection. The interconnection with motor’s equipment could also differ due to input and output signals required by standard models.
The asynchronous machine model is used to model wind generators Type 1 and Type 2. For these, normal practice is to include the rotor flux transients and neglect the stator flux transients.
AsynchronousMachineDynamics
Asynchronous machine whose behaviour is described by reference to a standard model expressed in either time constant reactance form or equivalent circuit form or by definition of a user-defined model.
Parameter Notes:
- Asynchronous machine parameters such as Xl, Xs etc. are actually used as inductances (L) in the model, but are commonly referred to as reactances since, at nominal frequency, the per unit values are the same. However, some references use the symbol L instead of X.
abstract
AsynchronousMachineDynamics
Asynchronous machine model with which this mechanical load model is associated.
Yes
MechanicalLoadDynamics
Mechanical load model associated with this asynchronous machine model.
MechanicalLoadDynamics
No
AsynchronousMachineDynamics
Asynchronous machine model with which this wind generator type 1 or 2 model is associated.
Yes
WindTurbineType1or2Dynamics
Wind generator type 1 or 2 model associated with this asynchronous machine model.
WindTurbineType1or2Dynamics
No
AsynchronousMachineDynamics
Asynchronous machine model with which this turbine-governor model is associated.
Yes
TurbineGovernorDynamics
Turbine-governor model associated with this asynchronous machine model.
TurbineGovernorDynamics
No
AsynchronousMachineTimeConstantReactance
Parameter Notes:
- If X'' = X', a single cage (one equivalent rotor winding per axis) is modelled.
- The “p” in the attribute names is a substitution for a “prime” in the usual parameter notation, e.g. tpo refers to T'o.
The parameters used for models expressed in time constant reactance form include:
- RotatingMachine.ratedS (MVAbase)
- RotatingMachineDynamics.damping (D)
- RotatingMachineDynamics.inertia (H)
- RotatingMachineDynamics.saturationFactor (S1)
- RotatingMachineDynamics.saturationFactor120 (S12)
- RotatingMachineDynamics.statorLeakageReactance (Xl)
- RotatingMachineDynamics.statorResistance (Rs)
- .xs (Xs)
- .xp (X')
- .xpp (X'')
- .tpo (T'o)
- .tppo (T''o).
xs
Synchronous reactance (Xs) (>= X'). Typical Value = 1.8.
xp
Transient reactance (unsaturated) (X') (>=X''). Typical Value = 0.5.
xpp
Subtransient reactance (unsaturated) (X'') (> Xl). Typical Value = 0.2.
tpo
Transient rotor time constant (T'o) (> T''o). Typical Value = 5.
tppo
Subtransient rotor time constant (T''o) (> 0). Typical Value = 0.03.
AsynchronousMachineEquivalentCircuit
The electrical equations of all variations of the asynchronous model are based on the AsynchronousEquivalentCircuit diagram for the direct and quadrature axes, with two equivalent rotor windings in each axis.
Equations for conversion between Equivalent Circuit and Time Constant Reactance forms:
Xs = Xm + Xl
X' = Xl + Xm * Xlr1 / (Xm + Xlr1)
X'' = Xl + Xm * Xlr1* Xlr2 / (Xm * Xlr1 + Xm * Xlr2 + Xlr1 * Xlr2)
T'o = (Xm + Xlr1) / (omega0 * Rr1)
T''o = (Xm * Xlr1 + Xm * Xlr2 + Xlr1 * Xlr2) / (omega0 * Rr2 * (Xm + Xlr1)
Same equations using CIM attributes from AsynchronousMachineTimeConstantReactance class on left of = sign and AsynchronousMachineEquivalentCircuit class on right (except as noted):
xs = xm + RotatingMachineDynamics.statorLeakageReactance
xp = RotatingMachineDynamics.statorLeakageReactance + xm * xlr1 / (xm + xlr1)
xpp = RotatingMachineDynamics.statorLeakageReactance + xm * xlr1* xlr2 / (xm * xlr1 + xm * xlr2 + xlr1 * xlr2)
tpo = (xm + xlr1) / (2*pi*nominal frequency * rr1)
tppo = (xm * xlr1 + xm * xlr2 + xlr1 * xlr2) / (2*pi*nominal frequency * rr2 * (xm + xlr1).
xm
Magnetizing reactance.
rr1
Damper 1 winding resistance.
xlr1
Damper 1 winding leakage reactance.
rr2
Damper 2 winding resistance.
xlr2
Damper 2 winding leakage reactance.
TurbineGovernorDynamics
The turbine-governor model is linked to one or two synchronous generators and determines the shaft mechanical power (Pm) or torque (Tm) for the generator model.
Unlike IEEE standard models for other function blocks, the three IEEE turbine-governor standard models (GovHydroIEEE0, GovHydroIEEE2, GovSteamIEEE1) are documented in IEEE Transactions not in IEEE standards. For that reason, diagrams are supplied for those models.
A 2012 IEEE report, Dynamic Models for Turbine-Governors in Power System Studies, provides updated information on a variety of models including IEEE, vendor and reliability authority models. Fully incorporating the results of that report into the CIM Dynamics model is a future effort.
TurbineGovernorDynamics
Turbine-governor function block whose behavior is described by reference to a standard model or by definition of a user-defined model.
abstract
TurbineGovernorDynamics
Turbine-governor controlled by this turbine load controller.
Yes
TurbineLoadControllerDynamics
Turbine load controller providing input to this turbine-governor.
TurbineLoadControllerDynamics
No
GovHydroIEEE0
IEEE Simplified Hydro Governor-Turbine Model. Used for Mechanical-Hydraulic and Electro-Hydraulic turbine governors, with our without steam feedback. Typical values given are for Mechanical-Hydraulic.
Reference: IEEE Transactions on Power Apparatus and Systems
November/December 1973, Volume PAS-92, Number 6
Dynamic Models for Steam and Hydro Turbines in Power System Studies, Page 1904.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
ActivePower
Product of RMS value of the voltage and the RMS value of the in-phase component of the current.
CIMDatatype
value
unit
multiplier
k
Governor gain (K).
t1
Governor lag time constant (T1). Typical Value = 0.25.
t2
Governor lead time constant (T2). Typical Value = 0.
t3
Gate actuator time constant (T3). Typical Value = 0.1.
t4
Water starting time (T4).
pmax
Gate maximum (Pmax).
pmin
Gate minimum (Pmin).
GovHydroIEEE2
IEEE hydro turbine governor model represents plants with straightforward penstock configurations and hydraulic-dashpot governors.
Reference: IEEE Transactions on Power Apparatus and Systems
November/December 1973, Volume PAS-92, Number 6
Dynamic Models for Steam and Hydro Turbines in Power System Studies, Page 1904.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
tg
Gate servo time constant (Tg). Typical Value = 0.5.
tp
Pilot servo valve time constant (Tp). Typical Value = 0.03.
uo
Maximum gate opening velocity (Uo). Unit = PU/sec. Typical Value = 0.1.
uc
Maximum gate closing velocity (Uc) (<0). Typical Value = -0.1.
pmax
Maximum gate opening (Pmax). Typical Value = 1.
pmin
Minimum gate opening (Pmin). Typical Value = 0.
rperm
Permanent droop (Rperm). Typical Value = 0.05.
rtemp
Temporary droop (Rtemp). Typical Value = 0.5.
tr
Dashpot time constant (Tr). Typical Value = 12.
tw
Water inertia time constant (Tw). Typical Value = 2.
kturb
Turbine gain (Kturb). Typical Value = 1.
aturb
Turbine numerator multiplier (Aturb). Typical Value = -1.
bturb
Turbine denominator multiplier (Bturb). Typical Value = 0.5.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovSteamIEEE1
IEEE steam turbine governor model.
Reference: IEEE Transactions on Power Apparatus and Systems
November/December 1973, Volume PAS-92, Number 6
Dynamic Models for Steam and Hydro Turbines in Power System Studies, Page 1904.
Parameter Notes:
- Per unit parameters are on base of MWbase, which is normally the MW capability of the turbine.
- T3 must be greater than zero. All other time constants may be zero.
- For a tandem-compound turbine the parameters K2, K4, K6, and K8 are ignored. For a cross-compound turbine, two generators are connected to this turbine-governor model.
- Each generator must be represented in the load flow by data on its own MVA base. The values of K1, K3, K5, K7 must be specified to describe the proportionate development of power on the first turbine shaft. K2, K4, K6, K8 must describe the second turbine shaft. Normally K1 + K3 + K5 + K7 = 1.0 and K2 + K4 + K6 + K8 = 1.0 (if second generator is present).
- The division of power between the two shafts is in proportion to the values of MVA bases of the two generators. The initial condition load flow should, therefore, have the two generators loaded to the same fraction of each one’s MVA base.
mwbase
Base for power values (MWbase) (> 0).
k
Governor gain (reciprocal of droop) (K) (> 0). Typical Value = 25.
t1
Governor lag time constant (T1). Typical Value = 0.
t2
Governor lead time constant (T2). Typical Value = 0.
t3
Valve positioner time constant (T3) (> 0). Typical Value = 0.1.
uo
Maximum valve opening velocity (Uo) (> 0). Unit = PU/sec. Typical Value = 1.
uc
Maximum valve closing velocity (Uc) (< 0). Unit = PU/sec. Typical Value = -10.
pmax
Maximum valve opening (Pmax) (> Pmin). Typical Value = 1.
pmin
Minimum valve opening (Pmin) (>= 0). Typical Value = 0.
t4
Inlet piping/steam bowl time constant (T4). Typical Value = 0.3.
k1
Fraction of HP shaft power after first boiler pass (K1). Typical Value = 0.2.
k2
Fraction of LP shaft power after first boiler pass (K2). Typical Value = 0.
t5
Time constant of second boiler pass (T5). Typical Value = 5.
k3
Fraction of HP shaft power after second boiler pass (K3). Typical Value = 0.3.
k4
Fraction of LP shaft power after second boiler pass (K4). Typical Value = 0.
t6
Time constant of third boiler pass (T6). Typical Value = 0.5.
k5
Fraction of HP shaft power after third boiler pass (K5). Typical Value = 0.5.
k6
Fraction of LP shaft power after third boiler pass (K6). Typical Value = 0.
t7
Time constant of fourth boiler pass (T7). Typical Value = 0.
k7
Fraction of HP shaft power after fourth boiler pass (K7). Typical Value = 0.
k8
Fraction of LP shaft power after fourth boiler pass (K8). Typical Value = 0.
GovCT1
General model for any prime mover with a PID governor, used primarily for combustion turbine and combined cycle units.
This model can be used to represent a variety of prime movers controlled by PID governors. It is suitable, for example, for representation of
- gas turbine and single shaft combined cycle turbines
- diesel engines with modern electronic or digital governors
- steam turbines where steam is supplied from a large boiler drum or a large header whose pressure is substantially constant over the period under study
- simple hydro turbines in dam configurations where the water column length is short and water inertia effects are minimal.
Additional information on this model is available in the 2012 IEEE report, Dynamic Models for Turbine-Governors in Power System Studies, section 3.1.2.3 page 3-4 (GGOV1).
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
r
Permanent droop (R). Typical Value = 0.04.
rselect
Feedback signal for droop (Rselect). Typical Value = electricalPower.
DroopSignalFeedbackKind
Governor droop signal feedback source.
electricalPower
Electrical power feedback (connection indicated as 1 in the block diagrams of models, e.g. GovCT1, GovCT2).
none
No droop signal feedback, is isochronous governor.
fuelValveStroke
Fuel valve stroke feedback (true stroke) (connection indicated as 2 in the block diagrams of model, e.g. GovCT1, GovCT2).
governorOutput
Governor output feedback (requested stroke) (connection indicated as 3 in the block diagrams of models, e.g. GovCT1, GovCT2).
tpelec
Electrical power transducer time constant (Tpelec) (>0). Typical Value = 1.
maxerr
Maximum value for speed error signal (maxerr). Typical Value = 0.05.
minerr
Minimum value for speed error signal (minerr). Typical Value = -0.05.
kpgov
Governor proportional gain (Kpgov). Typical Value = 10.
kigov
Governor integral gain (Kigov). Typical Value = 2.
kdgov
Governor derivative gain (Kdgov). Typical Value = 0.
tdgov
Governor derivative controller time constant (Tdgov). Typical Value = 1.
vmax
Maximum valve position limit (Vmax). Typical Value = 1.
vmin
Minimum valve position limit (Vmin). Typical Value = 0.15.
tact
Actuator time constant (Tact). Typical Value = 0.5.
kturb
Turbine gain (Kturb) (>0). Typical Value = 1.5.
wfnl
No load fuel flow (Wfnl). Typical Value = 0.2.
tb
Turbine lag time constant (Tb) (>0). Typical Value = 0.5.
tc
Turbine lead time constant (Tc). Typical Value = 0.
wfspd
Switch for fuel source characteristic to recognize that fuel flow, for a given fuel valve stroke, can be proportional to engine speed (Wfspd).
true = fuel flow proportional to speed (for some gas turbines and diesel engines with positive displacement fuel injectors)
false = fuel control system keeps fuel flow independent of engine speed.
Typical Value = true.
teng
Transport time delay for diesel engine used in representing diesel engines where there is a small but measurable transport delay between a change in fuel flow setting and the development of torque (Teng). Teng should be zero in all but special cases where this transport delay is of particular concern. Typical Value = 0.
tfload
Load Limiter time constant (Tfload) (>0). Typical Value = 3.
kpload
Load limiter proportional gain for PI controller (Kpload). Typical Value = 2.
kiload
Load limiter integral gain for PI controller (Kiload). Typical Value = 0.67.
ldref
Load limiter reference value (Ldref). Typical Value = 1.
dm
Speed sensitivity coefficient (Dm). Dm can represent either the variation of the engine power with the shaft speed or the variation of maximum power capability with shaft speed. If it is positive it describes the falling slope of the engine speed verses power characteristic as speed increases. A slightly falling characteristic is typical for reciprocating engines and some aero-derivative turbines. If it is negative the engine power is assumed to be unaffected by the shaft speed, but the maximum permissible fuel flow is taken to fall with falling shaft speed. This is characteristic of single-shaft industrial turbines due to exhaust temperature limits. Typical Value = 0.
ropen
Maximum valve opening rate (Ropen). Unit = PU/sec. Typical Value = 0.10.
rclose
Minimum valve closing rate (Rclose). Unit = PU/sec. Typical Value = -0.1.
kimw
Power controller (reset) gain (Kimw). The default value of 0.01 corresponds to a reset time of 100 seconds. A value of 0.001 corresponds to a relatively slow acting load controller. Typical Value = 0.01.
aset
Acceleration limiter setpoint (Aset). Unit = PU/sec. Typical Value = 0.01.
ka
Acceleration limiter gain (Ka). Typical Value = 10.
ta
Acceleration limiter time constant (Ta) (>0). Typical Value = 0.1.
db
Speed governor dead band in per unit speed (db). In the majority of applications, it is recommended that this value be set to zero. Typical Value = 0.
tsa
Temperature detection lead time constant (Tsa). Typical Value = 4.
tsb
Temperature detection lag time constant (Tsb). Typical Value = 5.
rup
Maximum rate of load limit increase (Rup). Typical Value = 99.
rdown
Maximum rate of load limit decrease (Rdown). Typical Value = -99.
GovCT2
General governor model with frequency-dependent fuel flow limit. This model is a modification of the GovCT1 model in order to represent the frequency-dependent fuel flow limit of a specific gas turbine manufacturer.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
r
Permanent droop (R). Typical Value = 0.05.
rselect
Feedback signal for droop (Rselect). Typical Value = electricalPower.
tpelec
Electrical power transducer time constant (Tpelec). Typical Value = 2.5.
maxerr
Maximum value for speed error signal (Maxerr). Typical Value = 1.
minerr
Minimum value for speed error signal (Minerr). Typical Value = -1.
kpgov
Governor proportional gain (Kpgov). Typical Value = 4.
kigov
Governor integral gain (Kigov). Typical Value = 0.45.
kdgov
Governor derivative gain (Kdgov). Typical Value = 0.
tdgov
Governor derivative controller time constant (Tdgov). Typical Value = 1.
vmax
Maximum valve position limit (Vmax). Typical Value = 1.
vmin
Minimum valve position limit (Vmin). Typical Value = 0.175.
tact
Actuator time constant (Tact). Typical Value = 0.4.
kturb
Turbine gain (Kturb). Typical Value = 1.9168.
wfnl
No load fuel flow (Wfnl). Typical Value = 0.187.
tb
Turbine lag time constant (Tb). Typical Value = 0.1.
tc
Turbine lead time constant (Tc). Typical Value = 0.
wfspd
Switch for fuel source characteristic to recognize that fuel flow, for a given fuel valve stroke, can be proportional to engine speed (Wfspd).
true = fuel flow proportional to speed (for some gas turbines and diesel engines with positive displacement fuel injectors)
false = fuel control system keeps fuel flow independent of engine speed.
Typical Value = false.
teng
Transport time delay for diesel engine used in representing diesel engines where there is a small but measurable transport delay between a change in fuel flow setting and the development of torque (Teng). Teng should be zero in all but special cases where this transport delay is of particular concern. Typical Value = 0.
tfload
Load Limiter time constant (Tfload). Typical Value = 3.
kpload
Load limiter proportional gain for PI controller (Kpload). Typical Value = 1.
kiload
Load limiter integral gain for PI controller (Kiload). Typical Value = 1.
ldref
Load limiter reference value (Ldref). Typical Value = 1.
dm
Speed sensitivity coefficient (Dm). Dm can represent either the variation of the engine power with the shaft speed or the variation of maximum power capability with shaft speed. If it is positive it describes the falling slope of the engine speed verses power characteristic as speed increases. A slightly falling characteristic is typical for reciprocating engines and some aero-derivative turbines. If it is negative the engine power is assumed to be unaffected by the shaft speed, but the maximum permissible fuel flow is taken to fall with falling shaft speed. This is characteristic of single-shaft industrial turbines due to exhaust temperature limits. Typical Value = 0.
ropen
Maximum valve opening rate (Ropen). Unit = PU/sec. Typical Value = 99.
rclose
Minimum valve closing rate (Rclose). Unit = PU/sec. Typical Value = -99.
kimw
Power controller (reset) gain (Kimw). The default value of 0.01 corresponds to a reset time of 100 seconds. A value of 0.001 corresponds to a relatively slow acting load controller. Typical Value = 0.
aset
Acceleration limiter setpoint (Aset). Unit = PU/sec. Typical Value = 10.
ka
Acceleration limiter Gain (Ka). Typical Value = 10.
ta
Acceleration limiter time constant (Ta). Typical Value = 1.
db
Speed governor dead band in per unit speed (db). In the majority of applications, it is recommended that this value be set to zero. Typical Value = 0.
tsa
Temperature detection lead time constant (Tsa). Typical Value = 0.
tsb
Temperature detection lag time constant (Tsb). Typical Value = 50.
rup
Maximum rate of load limit increase (Rup). Typical Value = 99.
rdown
Maximum rate of load limit decrease (Rdown). Typical Value = -99.
prate
Ramp rate for frequency-dependent power limit (Prate). Typical Value = 0.017.
flim1
Frequency threshold 1 (Flim1). Unit = Hz. Typical Value = 59.
Frequency
Cycles per second.
CIMDatatype
value
unit
multiplier
plim1
Power limit 1 (Plim1). Typical Value = 0.8325.
flim2
Frequency threshold 2 (Flim2). Unit = Hz. Typical Value = 0.
plim2
Power limit 2 (Plim2). Typical Value = 0.
flim3
Frequency threshold 3 (Flim3). Unit = Hz. Typical Value = 0.
plim3
Power limit 3 (Plim3). Typical Value = 0.
flim4
Frequency threshold 4 (Flim4). Unit = Hz. Typical Value = 0.
plim4
Power limit 4 (Plim4). Typical Value = 0.
flim5
Frequency threshold 5 (Flim5). Unit = Hz. Typical Value = 0.
plim5
Power limit 5 (Plim5). Typical Value = 0.
flim6
Frequency threshold 6 (Flim6). Unit = Hz. Typical Value = 0.
plim6
Power limit 6 (Plim6). Typical Value = 0.
flim7
Frequency threshold 7 (Flim7). Unit = Hz. Typical Value = 0.
plim7
Power limit 7 (Plim7). Typical Value = 0.
flim8
Frequency threshold 8 (Flim8). Unit = Hz. Typical Value = 0.
plim8
Power limit 8 (Plim8). Typical Value = 0.
flim9
Frequency threshold 9 (Flim9). Unit = Hz. Typical Value = 0.
plim9
Power Limit 9 (Plim9). Typical Value = 0.
flim10
Frequency threshold 10 (Flim10). Unit = Hz. Typical Value = 0.
plim10
Power limit 10 (Plim10). Typical Value = 0.
GovGAST
Single shaft gas turbine.
mwbase
Base for power values (MWbase) (> 0).
r
Permanent droop (R). Typical Value = 0.04.
t1
Governor mechanism time constant (T1). T1 represents the natural valve positioning time constant of the governor for small disturbances, as seen when rate limiting is not in effect. Typical Value = 0.5.
t2
Turbine power time constant (T2). T2 represents delay due to internal energy storage of the gas turbine engine. T2 can be used to give a rough approximation to the delay associated with acceleration of the compressor spool of a multi-shaft engine, or with the compressibility of gas in the plenum of a the free power turbine of an aero-derivative unit, for example. Typical Value = 0.5.
t3
Turbine exhaust temperature time constant (T3). Typical Value = 3.
at
Ambient temperature load limit (Load Limit). Typical Value = 1.
kt
Temperature limiter gain (Kt). Typical Value = 3.
vmax
Maximum turbine power, PU of MWbase (Vmax). Typical Value = 1.
vmin
Minimum turbine power, PU of MWbase (Vmin). Typical Value = 0.
dturb
Turbine damping factor (Dturb). Typical Value = 0.18.
GovGAST1
Modified single shaft gas turbine.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
r
Permanent droop (R). Typical Value = 0.04.
t1
Governor mechanism time constant (T1). T1 represents the natural valve positioning time constant of the governor for small disturbances, as seen when rate limiting is not in effect. Typical Value = 0.5.
t2
Turbine power time constant (T2). T2 represents delay due to internal energy storage of the gas turbine engine. T2 can be used to give a rough approximation to the delay associated with acceleration of the compressor spool of a multi-shaft engine, or with the compressibility of gas in the plenum of the free power turbine of an aero-derivative unit, for example. Typical Value = 0.5.
t3
Turbine exhaust temperature time constant (T3). T3 represents delay in the exhaust temperature and load limiting system. Typical Value = 3.
lmax
Ambient temperature load limit (Lmax). Lmax is the turbine power output corresponding to the limiting exhaust gas temperature. Typical Value = 1.
kt
Temperature limiter gain (Kt). Typical Value = 3.
vmax
Maximum turbine power, PU of MWbase (Vmax). Typical Value = 1.
vmin
Minimum turbine power, PU of MWbase (Vmin). Typical Value = 0.
fidle
Fuel flow at zero power output (Fidle). Typical Value = 0.18.
rmax
Maximum fuel valve opening rate (Rmax). Unit = PU/sec. Typical Value = 1.
loadinc
Valve position change allowed at fast rate (Loadinc). Typical Value = 0.05.
tltr
Valve position averaging time constant (Tltr). Typical Value = 10.
ltrate
Maximum long term fuel valve opening rate (Ltrate). Typical Value = 0.02.
a
Turbine power time constant numerator scale factor (a). Typical Value = 0.8.
b
Turbine power time constant denominator scale factor (b). Typical Value = 1.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2,PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
ka
Governor gain (Ka). Typical Value = 0.
t4
Governor lead time constant (T4). Typical Value = 0.
t5
Governor lag time constant (T5). Typical Value = 0.
GovGAST2
Gas turbine model.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
w
Governor gain (1/droop) on turbine rating (W).
x
Governor lead time constant (X).
y
Governor lag time constant (Y) (>0).
z
Governor mode (Z).
true = Droop
false = ISO.
etd
Turbine and exhaust delay (Etd).
tcd
Compressor discharge time constant (Tcd).
trate
Turbine rating (Trate). Unit = MW.
t
Fuel Control Time Constant (T).
tmax
Maximum Turbine limit (Tmax).
tmin
Minimum Turbine limit (Tmin).
ecr
Combustion reaction time delay (Ecr).
k3
Ratio of Fuel Adjustment (K3).
a
Valve positioner (A).
b
Valve positioner (B).
c
Valve positioner (C).
tf
Fuel system time constant (Tf).
kf
Fuel system feedback (Kf).
k5
Gain of radiation shield (K5).
k4
Gain of radiation shield (K4).
t3
Radiation shield time constant (T3).
t4
Thermocouple time constant (T4).
tt
Temperature controller integration rate (Tt).
t5
Temperature control time constant (T5).
af1
Exhaust temperature Parameter (Af1). Unit = per unit temperature. Based on temperature in degrees C.
bf1
(Bf1). Bf1 = E(1-w) where E (speed sensitivity coefficient) is 0.55 to 0.65 x Tr. Unit = per unit temperature. Based on temperature in degrees C.
af2
Coefficient equal to 0.5(1-speed) (Af2).
bf2
Turbine Torque Coefficient Khhv (depends on heating value of fuel stream in combustion chamber) (Bf2).
cf2
Coefficient defining fuel flow where power output is 0% (Cf2). Synchronous but no output. Typically 0.23 x Khhv (23% fuel flow).
tr
Rated temperature (Tr). Unit = °C depending on parameters Af1 and Bf1.
Temperature
Value of temperature in degrees Celsius.
CIMDatatype
multiplier
unit
value
k6
Minimum fuel flow (K6).
tc
Temperature control (Tc). Unit = °F or °C depending on constants Af1 and Bf1.
GovGAST3
Generic turbogas with acceleration and temperature controller.
bp
Droop (bp). Typical Value = 0.05.
tg
Time constant of speed governor (Tg). Typical Value = 0.05.
rcmx
Maximum fuel flow (RCMX). Typical Value = 1.
rcmn
Minimum fuel flow (RCMN). Typical Value = -0.1.
ky
Coefficient of transfer function of fuel valve positioner (Ky). Typical Value = 1.
ty
Time constant of fuel valve positioner (Ty). Typical Value = 0.2.
tac
Fuel control time constant (Tac). Typical Value = 0.1.
kac
Fuel system feedback (KAC). Typical Value = 0.
tc
Compressor discharge volume time constant (Tc). Typical Value = 0.2.
bca
Acceleration limit set-point (Bca). Unit = 1/s. Typical Value = 0.01.
kca
Acceleration control integral gain (Kca). Unit = 1/s. Typical Value = 100.
dtc
Exhaust temperature variation due to fuel flow increasing from 0 to 1 PU (deltaTc). Typical Value = 390.
ka
Minimum fuel flow (Ka). Typical Value = 0.23.
tsi
Time constant of radiation shield (Tsi). Typical Value = 15.
ksi
Gain of radiation shield (Ksi). Typical Value = 0.8.
ttc
Time constant of thermocouple (Ttc). Typical Value = 2.5.
tfen
Turbine rated exhaust temperature correspondent to Pm=1 PU (Tfen). Typical Value = 540.
td
Temperature controller derivative gain (Td). Typical Value = 3.3.
tt
Temperature controller integration rate (Tt). Typical Value = 250.
mxef
Fuel flow maximum positive error value (MXEF). Typical Value = 0.05.
mnef
Fuel flow maximum negative error value (MNEF). Typical Value = -0.05.
GovGAST4
Generic turbogas.
bp
Droop (bp). Typical Value = 0.05.
tv
Time constant of fuel valve positioner (Ty). Typical Value = 0.1.
ta
Maximum gate opening velocity (TA). Typical Value = 3.
tc
Maximum gate closing velocity (Tc). Typical Value = 0.5.
tcm
Fuel control time constant (Tcm). Typical Value = 0.1.
ktm
Compressor gain (Ktm). Typical Value = 0.
tm
Compressor discharge volume time constant (Tm). Typical Value = 0.2.
rymx
Maximum valve opening (RYMX). Typical Value = 1.1.
rymn
Minimum valve opening (RYMN). Typical Value = 0.
mxef
Fuel flow maximum positive error value (MXEF). Typical Value = 0.05.
mnef
Fuel flow maximum negative error value (MNEF). Typical Value = -0.05.
GovGASTWD
Woodward Gas turbine governor model.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
kdroop
(Kdroop).
kp
PID Proportional gain (Kp).
ki
Isochronous Governor Gain (Ki).
kd
Drop Governor Gain (Kd).
etd
Turbine and exhaust delay (Etd).
tcd
Compressor discharge time constant (Tcd).
trate
Turbine rating (Trate). Unit = MW.
t
Fuel Control Time Constant (T).
tmax
Maximum Turbine limit (Tmax).
tmin
Minimum Turbine limit (Tmin).
ecr
Combustion reaction time delay (Ecr).
k3
Ratio of Fuel Adjustment (K3).
a
Valve positioner (A).
b
Valve positioner (B).
c
Valve positioner (C).
tf
Fuel system time constant (Tf).
kf
Fuel system feedback (Kf).
k5
Gain of radiation shield (K5).
k4
Gain of radiation shield (K4).
t3
Radiation shield time constant (T3).
t4
Thermocouple time constant (T4).
tt
Temperature controller integration rate (Tt).
t5
Temperature control time constant (T5).
af1
Exhaust temperature Parameter (Af1).
bf1
(Bf1). Bf1 = E(1-w) where E (speed sensitivity coefficient) is 0.55 to 0.65 x Tr.
af2
Coefficient equal to 0.5(1-speed) (Af2).
bf2
Turbine Torque Coefficient Khhv (depends on heating value of fuel stream in combustion chamber) (Bf2).
cf2
Coefficient defining fuel flow where power output is 0% (Cf2). Synchronous but no output. Typically 0.23 x Khhv (23% fuel flow).
tr
Rated temperature (Tr).
k6
Minimum fuel flow (K6).
tc
Temperature control (Tc).
td
Power transducer time constant (Td).
GovHydro1
Basic Hydro turbine governor model.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
rperm
Permanent droop (R) (>0). Typical Value = 0.04.
rtemp
Temporary droop (r) (>R). Typical Value = 0.3.
tr
Washout time constant (Tr) (>0). Typical Value = 5.
tf
Filter time constant (Tf) (>0). Typical Value = 0.05.
tg
Gate servo time constant (Tg) (>0). Typical Value = 0.5.
velm
Maximum gate velocity (Vlem) (>0). Typical Value = 0.2.
gmax
Maximum gate opening (Gmax) (>0). Typical Value = 1.
gmin
Minimum gate opening (Gmin) (>=0). Typical Value = 0.
tw
Water inertia time constant (Tw) (>0). Typical Value = 1.
at
Turbine gain (At) (>0). Typical Value = 1.2.
dturb
Turbine damping factor (Dturb) (>=0). Typical Value = 0.5.
qnl
No-load flow at nominal head (qnl) (>=0). Typical Value = 0.08.
hdam
Turbine nominal head (hdam). Typical Value = 1.
GovHydro2
IEEE hydro turbine governor model represents plants with straightforward penstock configurations and hydraulic-dashpot governors.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
tg
Gate servo time constant (Tg). Typical Value = 0.5.
tp
Pilot servo valve time constant (Tp). Typical Value = 0.03.
uo
Maximum gate opening velocity (Uo). Unit = PU/sec. Typical Value = 0.1.
uc
Maximum gate closing velocity (Uc) (<0). Unit = PU/sec. Typical Value = -0.1.
pmax
Maximum gate opening (Pmax). Typical Value = 1.
pmin
Minimum gate opening; (Pmin). Typical Value = 0.
rperm
Permanent droop (Rperm). Typical Value = 0.05.
rtemp
Temporary droop (Rtemp). Typical Value = 0.5.
tr
Dashpot time constant (Tr). Typical Value = 12.
tw
Water inertia time constant (Tw). Typical Value = 2.
kturb
Turbine gain (Kturb). Typical Value = 1.
aturb
Turbine numerator multiplier (Aturb). Typical Value = -1.
bturb
Turbine denominator multiplier (Bturb). Typical Value = 0.5.
db1
Intentional deadband width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional deadband (db2). Unit = MW. Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovHydro3
Modified IEEE Hydro Governor-Turbine Model.
This model differs from that defined in the IEEE modeling guideline paper in that the limits on gate position and velocity do not permit "wind up" of the upstream signals.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
pmax
Maximum gate opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum gate opening, PU of MWbase (Pmin). Typical Value = 0.
governorControl
Governor control flag (Cflag).
true = PID control is active
false = double derivative control is active.
Typical Value = true.
rgate
Steady-state droop, PU, for governor output feedback (Rgate). Typical Value = 0.
relec
Steady-state droop, PU, for electrical power feedback (Relec). Typical Value = 0.05.
td
Input filter time constant (Td). Typical Value = 0.05.
tf
Washout time constant (Tf). Typical Value = 0.1.
tp
Gate servo time constant (Tp). Typical Value = 0.05.
velop
Maximum gate opening velocity (Velop). Unit = PU/sec. Typical Value = 0.2.
velcl
Maximum gate closing velocity (Velcl). Unit = PU/sec. Typical Value = -0.2.
k1
Derivative gain (K1). Typical Value = 0.01.
k2
Double derivative gain, if Cflag = -1 (K2). Typical Value = 2.5.
ki
Integral gain (Ki). Typical Value = 0.5.
kg
Gate servo gain (Kg). Typical Value = 2.
tt
Power feedback time constant (Tt). Typical Value = 0.2.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
tw
Water inertia time constant (Tw). Typical Value = 1.
at
Turbine gain (At). Typical Value = 1.2.
dturb
Turbine damping factor (Dturb). Typical Value = 0.2.
qnl
No-load turbine flow at nominal head (Qnl). Typical Value = 0.08.
h0
Turbine nominal head (H0). Typical Value = 1.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovHydro4
Hydro turbine and governor. Represents plants with straight-forward penstock configurations and hydraulic governors of traditional 'dashpot' type. This model can be used to represent simple, Francis, Pelton or Kaplan turbines.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
tg
Gate servo time constant (Tg) (>0). Typical Value = 0.5.
tp
Pilot servo time constant (Tp). Typical Value = 0.1.
uo
Max gate opening velocity (Uo). Typical Vlaue = 0.2.
uc
Max gate closing velocity (Uc). Typical Value = 0.2.
gmax
Maximum gate opening, PU of MWbase (Gmax). Typical Value = 1.
gmin
Minimum gate opening, PU of MWbase (Gmin). Typical Value = 0.
rperm
Permanent droop (Rperm). Typical Value = 0.05.
rtemp
Temporary droop (Rtemp). Typical Value = 0.3.
tr
Dashpot time constant (Tr) (>0). Typical Value = 5.
tw
Water inertia time constant (Tw) (>0). Typical Value = 1.
at
Turbine gain (At). Typical Value = 1.2.
dturb
Turbine damping factor (Dturb). Unit = delta P (PU of MWbase) / delta speed (PU).
Typical Value = 0.5. Typical Value Francis = 1.1, Kaplan = 1.1.
hdam
Head available at dam (hdam). Typical Value = 1.
qn1
No-load flow at nominal head (Qnl).
Typical Value = 0.08. Typical Value Francis = 0, Kaplan = 0.
db1
Intentional deadband width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
gv0
Nonlinear gain point 0, PU gv (Gv0).
Typical Value = 0. Typical Value Francis = 0.1, Kaplan = 0.1.
pgv0
Nonlinear gain point 0, PU power (Pgv0). Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1).
Typical Value = 0. Typical Value Francis = 0.4, Kaplan = 0.4.
pgv1
Nonlinear gain point 1, PU power (Pgv1).
Typical Value = 0. Typical Value Francis = 0.42, Kaplan = 0.35.
gv2
Nonlinear gain point 2, PU gv (Gv2).
Typical Value = 0. Typical Value Francis = 0.5, Kaplan = 0.5.
pgv2
Nonlinear gain point 2, PU power (Pgv2).
Typical Value = 0. Typical Value Francis = 0.56, Kaplan = 0.468.
gv3
Nonlinear gain point 3, PU gv (Gv3).
Typical Value = 0. Typical Value Francis = 0.7, Kaplan = 0.7.
pgv3
Nonlinear gain point 3, PU power (Pgv3).
Typical Value = 0. Typical Value Francis = 0.8, Kaplan = 0.796.
gv4
Nonlinear gain point 4, PU gv (Gv4).
Typical Value = 0. Typical Value Francis = 0.8, Kaplan = 0.8.
pgv4
Nonlinear gain point 4, PU power (Pgv4).
Typical Value = 0. Typical Value Francis = 0.9, Kaplan = 0.917.
gv5
Nonlinear gain point 5, PU gv (Gv5).
Typical Value = 0. Typical Value Francis = 0.9, Kaplan = 0.9.
pgv5
Nonlinear gain point 5, PU power (Pgv5).
Typical Value = 0. Typical Value Francis = 0.97, Kaplan = 0.99.
bgv0
Kaplan blade servo point 0 (Bgv0). Typical Value = 0.
bgv1
Kaplan blade servo point 1 (Bgv1). Typical Value = 0.
bgv2
Kaplan blade servo point 2 (Bgv2).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 0.1.
bgv3
Kaplan blade servo point 3 (Bgv3).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 0.667.
bgv4
Kaplan blade servo point 4 (Bgv4).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 0.9.
bgv5
Kaplan blade servo point 5 (Bgv5).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 1.
bmax
Maximum blade adjustment factor (Bmax).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 1.1276.
tblade
Blade servo time constant (Tblade). Typical Value = 100.
GovHydroDD
Double derivative hydro governor and turbine.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
pmax
Maximum gate opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum gate opening, PU of MWbase (Pmin). Typical Value = 0.
r
Steady state droop (R). Typical Value = 0.05.
td
Input filter time constant (Td). Typical Value = 0.
tf
Washout time constant (Tf). Typical Value = 0.1.
tp
Gate servo time constant (Tp). Typical Value = 0.35.
velop
Maximum gate opening velocity (Velop). Unit = PU/sec. Typical Value = 0.09.
velcl
Maximum gate closing velocity (Velcl). Unit = PU/sec. Typical Value = -0.14.
k1
Single derivative gain (K1). Typical Value = 3.6.
k2
Double derivative gain (K2). Typical Value = 0.2.
ki
Integral gain (Ki). Typical Value = 1.
kg
Gate servo gain (Kg). Typical Value = 3.
tturb
Turbine time constant (Tturb) (note 3). Typical Value = 0.8.
aturb
Turbine numerator multiplier (Aturb) (note 3). Typical Value = -1.
bturb
Turbine denominator multiplier (Bturb) (note 3). Typical Value = 0.5.
tt
Power feedback time constant (Tt). Typical Value = 0.02.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
gmax
Maximum gate opening (Gmax). Typical Value = 0.
gmin
Minimum gate opening (Gmin). Typical Value = 0.
inputSignal
Input signal switch (Flag).
true = Pe input is used
false = feedback is received from CV.
Flag is normally dependent on Tt. If Tf is zero, Flag is set to false. If Tf is not zero, Flag is set to true.
Typical Value = true.
GovHydroFrancis
Detailed hydro unit - Francis model. This model can be used to represent three types of governors.
A schematic of the hydraulic system of detailed hydro unit models, like Francis and Pelton, is provided in the DetailedHydroModelHydraulicSystem diagram.
am
Opening section Seff at the maximum efficiency (Am). Typical Value = 0.7.
av0
Area of the surge tank (AV0). Unit = m2. Typical Value = 30.
Area
Area.
CIMDatatype
value
unit
multiplier
av1
Area of the compensation tank (AV1). Unit = m2. Typical Value = 700.
bp
Droop (Bp). Typical Value = 0.05.
db1
Intentional dead-band width (DB1). Unit = Hz. Typical Value = 0.
etamax
Maximum efficiency (EtaMax). Typical Value = 1.05.
governorControl
Governor control flag (Cflag). Typical Value = mechanicHydrolicTachoAccelerator.
FrancisGovernorControlKind
Governor control flag for Francis hydro model.
mechanicHydrolicTachoAccelerator
Mechanic-hydraulic regulator with tacho-accelerometer (Cflag = 1).
mechanicHydraulicTransientFeedback
Mechanic-hydraulic regulator with transient feedback (Cflag=2).
electromechanicalElectrohydraulic
Electromechanical and electrohydraulic regulator (Cflag=3).
h1
Head of compensation chamber water level with respect to the level of penstock (H1). Unit = m. Typical Value = 4.
Length
Unit of length. Never negative.
CIMDatatype
value
unit
multiplier
h2
Head of surge tank water level with respect to the level of penstock (H2). Unit = m. Typical Value = 40.
hn
Rated hydraulic head (Hn). Unit = m. Typical Value = 250.
kc
Penstock loss coefficient (due to friction) (Kc). Typical Value = 0.025.
kg
Water tunnel and surge chamber loss coefficient (due to friction) (Kg). Typical Value = 0.025.
kt
Washout gain (Kt). Typical Value = 0.25.
qc0
No-load turbine flow at nominal head (Qc0). Typical Value = 0.21.
qn
Rated flow (Qn). Unit = m3/s. Typical Value = 40.
VolumeFlowRate
Volume per time.
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
ta
Derivative gain (Ta). Typical Value = 3.
td
Washout time constant (Td). Typical Value = 3.
ts
Gate servo time constant (Ts). Typical Value = 0.5.
twnc
Water inertia time constant (Twnc). Typical Value = 1.
twng
Water tunnel and surge chamber inertia time constant (Twng). Typical Value = 3.
tx
Derivative feedback gain (Tx). Typical Value = 1.
va
Maximum gate opening velocity (Va). Unit = PU/sec. Typical Value = 0.011.
valvmax
Maximum gate opening (ValvMax). Typical Value = 1.
valvmin
Minimum gate opening (ValvMin). Typical Value = 0.
vc
Maximum gate closing velocity (Vc). Unit = PU/sec. Typical Value = -0.011.
waterTunnelSurgeChamberSimulation
Water tunnel and surge chamber simulation (Tflag).
true = enable of water tunnel and surge chamber simulation
false = inhibit of water tunnel and surge chamber simulation.
Typical Value = false.
zsfc
Head of upper water level with respect to the level of penstock (Zsfc). Unit = m. Typical Value = 25.
GovHydroPelton
Detailed hydro unit - Pelton model. This model can be used to represent the dynamic related to water tunnel and surge chamber.
A schematic of the hydraulic system of detailed hydro unit models, like Francis and Pelton, is located under the GovHydroFrancis class.
av0
Area of the surge tank (AV0). Unit = m2. Typical Value = 30.
av1
Area of the compensation tank (AV1). Unit = m2. Typical Value = 700.
bp
Droop (bp). Typical Value = 0.05.
db1
Intentional dead-band width (DB1). Unit = Hz. Typical Value = 0.
db2
Intentional dead-band width of valve opening error (DB2). Unit = Hz. Typical Value = 0.01.
h1
Head of compensation chamber water level with respect to the level of penstock (H1). Unit = m. Typical Value = 4.
h2
Head of surge tank water level with respect to the level of penstock (H2). Unit = m. Typical Value = 40.
hn
Rated hydraulic head (Hn). Unit = m. Typical Value = 250.
kc
Penstock loss coefficient (due to friction) (Kc). Typical Value = 0.025.
kg
Water tunnel and surge chamber loss coefficient (due to friction) (Kg). Typical Value = -0.025.
qc0
No-load turbine flow at nominal head (Qc0). Typical Value = 0.05.
qn
Rated flow (Qn). Unit = m3/s. Typical Value = 40.
simplifiedPelton
Simplified Pelton model simulation (Sflag).
true = enable of simplified Pelton model simulation
false = enable of complete Pelton model simulation (non linear gain).
Typical Value = false.
staticCompensating
Static compensating characteristic (Cflag).
true = enable of static compensating characteristic
false = inhibit of static compensating characteristic.
Typical Value = false.
ta
Derivative gain (accelerometer time constant) (Ta). Typical Value = 3.
ts
Gate servo time constant (Ts). Typical Value = 0.15.
tv
Servomotor integrator time constant (TV). Typical Value = 0.3.
twnc
Water inertia time constant (Twnc). Typical Value = 1.
twng
Water tunnel and surge chamber inertia time constant (Twng). Typical Value = 3.
tx
Electronic integrator time constant (Tx). Typical Value = 0.5.
va
Maximum gate opening velocity (Va). Unit = PU/sec. Typical Value = 0.016.
valvmax
Maximum gate opening (ValvMax). Typical Value = 1.
valvmin
Minimum gate opening (ValvMin). Typical Value = 0.
vav
Maximum servomotor valve opening velocity (Vav). Typical Value = 0.017.
vc
Maximum gate closing velocity (Vc). Unit = PU/sec. Typical Value = -0.016.
vcv
Maximum servomotor valve closing velocity (Vcv). Typical Value = -0.017.
waterTunnelSurgeChamberSimulation
Water tunnel and surge chamber simulation (Tflag).
true = enable of water tunnel and surge chamber simulation
false = inhibit of water tunnel and surge chamber simulation.
Typical Value = false.
zsfc
Head of upper water level with respect to the level of penstock (Zsfc). Unit = m. Typical Value = 25.
GovHydroPID
PID governor and turbine.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
pmax
Maximum gate opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum gate opening, PU of MWbase (Pmin). Typical Value = 0.
r
Steady state droop (R). Typical Value = 0.05.
td
Input filter time constant (Td). Typical Value = 0.
tf
Washout time constant (Tf). Typical Value = 0.1.
tp
Gate servo time constant (Tp). Typical Value = 0.35.
velop
Maximum gate opening velocity (Velop). Unit = PU/sec. Typical Value = 0.09.
velcl
Maximum gate closing velocity (Velcl). Unit = PU/sec. Typical Value = -0.14.
kd
Derivative gain (Kd). Typical Value = 1.11.
kp
Proportional gain (Kp). Typical Value = 0.1.
ki
Integral gain (Ki). Typical Value = 0.36.
kg
Gate servo gain (Kg). Typical Value = 2.5.
tturb
Turbine time constant (Tturb) (note 3). Typical Value = 0.8.
aturb
Turbine numerator multiplier (Aturb) (note 3). Typical Value -1.
bturb
Turbine denominator multiplier (Bturb) (note 3). Typical Value = 0.5.
tt
Power feedback time constant (Tt). Typical Value = 0.02.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
inputSignal
Input signal switch (Flag).
true = Pe input is used
false = feedback is received from CV.
Flag is normally dependent on Tt. If Tf is zero, Flag is set to false. If Tf is not zero, Flag is set to true. Typical Value = true.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovHydroPID2
Hydro turbine and governor. Represents plants with straight forward penstock configurations and "three term" electro-hydraulic governors (i.e. Woodard electronic).
mwbase
Base for power values (MWbase) (>0). Unit = MW.
treg
Speed detector time constant (Treg). Typical Value = 0.
rperm
Permanent drop (Rperm). Typical Value = 0.
kp
Proportional gain (Kp). Typical Value = 0.
ki
Reset gain (Ki). Unit = PU/ sec. Typical Value = 0.
kd
Derivative gain (Kd). Typical Value = 0.
ta
Controller time constant (Ta) (>0). Typical Value = 0.
tb
Gate servo time constant (Tb) (>0). Typical Value = 0.
velmax
Maximum gate opening velocity (Velmax). Unit = PU/sec. Typical Value = 0.
velmin
Maximum gate closing velocity (Velmin). Unit = PU/sec. Typical Value = 0.
gmax
Maximum gate opening (Gmax). Typical Value = 0.
gmin
Minimum gate opening (Gmin). Typical Value = 0.
tw
Water inertia time constant (Tw) (>0). Typical Value = 0.
d
Turbine damping factor (D). Unit = delta P / delta speed. Typical Value = 0.
g0
Gate opening at speed no load (G0). Typical Value = 0.
g1
Intermediate gate opening (G1). Typical Value = 0.
p1
Power at gate opening G1 (P1). Typical Value = 0.
g2
Intermediate gate opening (G2). Typical Value = 0.
p2
Power at gate opening G2 (P2). Typical Value = 0.
p3
Power at full opened gate (P3). Typical Value = 0.
atw
Factor multiplying Tw (Atw). Typical Value = 0.
feedbackSignal
Feedback signal type flag (Flag).
true = use gate position feedback signal
false = use Pe.
GovHydroR
Fourth order lead-lag governor and hydro turbine.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
pmax
Maximum gate opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum gate opening, PU of MWbase (Pmin). Typical Value = 0.
r
Steady-state droop (R). Typical Value = 0.05.
td
Input filter time constant (Td). Typical Value = 0.05.
t1
Lead time constant 1 (T1). Typical Value = 1.5.
t2
Lag time constant 1 (T2). Typical Value = 0.1.
t3
Lead time constant 2 (T3). Typical Value = 1.5.
t4
Lag time constant 2 (T4). Typical Value = 0.1.
t5
Lead time constant 3 (T5). Typical Value = 0.
t6
Lag time constant 3 (T6). Typical Value = 0.05.
t7
Lead time constant 4 (T7). Typical Value = 0.
t8
Lag time constant 4 (T8). Typical Value = 0.05.
tp
Gate servo time constant (Tp). Typical Value = 0.05.
velop
Maximum gate opening velocity (Velop). Unit = PU/sec. Typical Value = 0.2.
velcl
Maximum gate closing velocity (Velcl). Unit = PU/sec. Typical Value = -0.2.
ki
Integral gain (Ki). Typical Value = 0.5.
kg
Gate servo gain (Kg). Typical Value = 2.
gmax
Maximum governor output (Gmax). Typical Value = 1.05.
gmin
Minimum governor output (Gmin). Typical Value = -0.05.
tt
Power feedback time constant (Tt). Typical Value = 0.
inputSignal
Input signal switch (Flag).
true = Pe input is used
false = feedback is received from CV.
Flag is normally dependent on Tt. If Tf is zero, Flag is set to false. If Tf is not zero, Flag is set to true. Typical Value = true.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
tw
Water inertia time constant (Tw). Typical Value = 1.
at
Turbine gain (At). Typical Value = 1.2.
dturb
Turbine damping factor (Dturb). Typical Value = 0.2.
qnl
No-load turbine flow at nominal head (Qnl). Typical Value = 0.08.
h0
Turbine nominal head (H0). Typical Value = 1.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovHydroWEH
Woodward Electric Hydro Governor Model.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
rpg
Permanent droop for governor output feedback (R-Perm-Gate).
rpp
Permanent droop for electrical power feedback (R-Perm-Pe).
tpe
Electrical power droop time constant (Tpe).
kp
Derivative control gain (Kp).
ki
Derivative controller Integral gain (Ki).
kd
Derivative controller derivative gain (Kd).
td
Derivative controller time constant to limit the derivative characteristic beyond a breakdown frequency to avoid amplification of high-frequency noise (Td).
tp
Pilot Valve time lag time constant (Tp).
tdv
Distributive Valve time lag time constant (Tdv).
tg
Value to allow the Distribution valve controller to advance beyond the gate movement rate limit (Tg).
gtmxop
Maximum gate opening rate (Gtmxop).
gtmxcl
Maximum gate closing rate (Gtmxcl).
gmax
Maximum Gate Position (Gmax).
gmin
Minimum Gate Position (Gmin).
dturb
Turbine damping factor (Dturb). Unit = delta P (PU of MWbase) / delta speed (PU).
tw
Water inertia time constant (Tw) (>0).
db
Speed Dead Band (db).
dpv
Value to allow the Pilot valve controller to advance beyond the gate limits (Dpv).
dicn
Value to allow the integral controller to advance beyond the gate limits (Dicn).
feedbackSignal
Feedback signal selection (Sw).
true = PID Output (if R-Perm-Gate=droop and R-Perm-Pe=0)
false = Electrical Power (if R-Perm-Gate=0 and R-Perm-Pe=droop) or
false = Gate Position (if R-Perm-Gate=droop and R-Perm-Pe=0).
gv1
Gate 1 (Gv1). Gate Position value for point 1 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
gv2
Gate 2 (Gv2). Gate Position value for point 2 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
gv3
Gate 3 (Gv3). Gate Position value for point 3 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
gv4
Gate 4 (Gv4). Gate Position value for point 4 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
gv5
Gate 5 (Gv5). Gate Position value for point 5 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl1
Flow Gate 1 (Fl1). Flow value for gate position point 1 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl2
Flow Gate 2 (Fl2). Flow value for gate position point 2 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl3
Flow Gate 3 (Fl3). Flow value for gate position point 3 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl4
Flow Gate 4 (Fl4). Flow value for gate position point 4 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl5
Flow Gate 5 (Fl5). Flow value for gate position point 5 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fp1
Flow P1 (Fp1). Turbine Flow value for point 1 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp2
Flow P2 (Fp2). Turbine Flow value for point 2 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp3
Flow P3 (Fp3). Turbine Flow value for point 3 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp4
Flow P4 (Fp4). Turbine Flow value for point 4 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp5
Flow P5 (Fp5). Turbine Flow value for point 5 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp6
Flow P6 (Fp6). Turbine Flow value for point 6 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp7
Flow P7 (Fp7). Turbine Flow value for point 7 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp8
Flow P8 (Fp8). Turbine Flow value for point 8 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp9
Flow P9 (Fp9). Turbine Flow value for point 9 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp10
Flow P10 (Fp10). Turbine Flow value for point 10 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss1
Pmss Flow P1 (Pmss1). Mechanical Power output Pmss for Turbine Flow point 1 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss2
Pmss Flow P2 (Pmss2). Mechanical Power output Pmss for Turbine Flow point 2 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss3
Pmss Flow P3 (Pmss3). Mechanical Power output Pmss for Turbine Flow point 3 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss4
Pmss Flow P4 (Pmss4). Mechanical Power output Pmss for Turbine Flow point 4 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss5
Pmss Flow P5 (Pmss5). Mechanical Power output Pmss for Turbine Flow point 5 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss6
Pmss Flow P6 (Pmss6). Mechanical Power output Pmss for Turbine Flow point 6 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss7
Pmss Flow P7 (Pmss7). Mechanical Power output Pmss for Turbine Flow point 7 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss8
Pmss Flow P8 (Pmss8). Mechanical Power output Pmss for Turbine Flow point 8 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss9
Pmss Flow P9 (Pmss9). Mechanical Power output Pmss for Turbine Flow point 9 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss10
Pmss Flow P10 (Pmss10). Mechanical Power output Pmss for Turbine Flow point 10 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
GovHydroWPID
Woodward PID Hydro Governor.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
treg
Speed detector time constant (Treg).
reg
Permanent drop (Reg).
kp
Proportional gain (Kp). Typical Value = 0.1.
ki
Reset gain (Ki). Typical Value = 0.36.
kd
Derivative gain (Kd). Typical Value = 1.11.
ta
Controller time constant (Ta) (>0). Typical Value = 0.
tb
Gate servo time constant (Tb) (>0). Typical Value = 0.
velmax
Maximum gate opening velocity (Velmax). Unit = PU/sec. Typical Value = 0.
velmin
Maximum gate closing velocity (Velmin). Unit = PU/sec. Typical Value = 0.
gatmax
Gate opening Limit Maximum (Gatmax).
gatmin
Gate opening Limit Minimum (Gatmin).
tw
Water inertia time constant (Tw) (>0). Typical Value = 0.
pmax
Maximum Power Output (Pmax).
pmin
Minimum Power Output (Pmin).
d
Turbine damping factor (D). Unit = delta P / delta speed.
gv3
Gate position 3 (Gv3).
gv1
Gate position 1 (Gv1).
pgv1
Output at Gv1 PU of MWbase (Pgv1).
gv2
Gate position 2 (Gv2).
pgv2
Output at Gv2 PU of MWbase (Pgv2).
pgv3
Output at Gv3 PU of MWbase (Pgv3).
GovSteam0
A simplified steam turbine governor model.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
r
Permanent droop (R). Typical Value = 0.05.
t1
Steam bowl time constant (T1). Typical Value = 0.5.
vmax
Maximum valve position, PU of mwcap (Vmax). Typical Value = 1.
vmin
Minimum valve position, PU of mwcap (Vmin). Typical Value = 0.
t2
Numerator time constant of T2/T3 block (T2). Typical Value = 3.
t3
Reheater time constant (T3). Typical Value = 10.
dt
Turbine damping coefficient (Dt). Unit = delta P / delta speed. Typical Value = 0.
GovSteam1
Steam turbine governor model, based on the GovSteamIEEE1 model (with optional deadband and nonlinear valve gain added).
mwbase
Base for power values (MWbase) (>0). Unit = MW.
k
Governor gain (reciprocal of droop) (K) (>0). Typical Value = 25.
t1
Governor lag time constant (T1). Typical Value = 0.
t2
Governor lead time constant (T2). Typical Value = 0.
t3
Valve positioner time constant (T3) (>0). Typical Value = 0.1.
uo
Maximum valve opening velocity (Uo) (>0). Unit = PU/sec. Typical Value = 1.
uc
Maximum valve closing velocity (Uc) (<0). Unit = PU/sec. Typical Value = -10.
pmax
Maximum valve opening (Pmax) (> Pmin). Typical Value = 1.
pmin
Minimum valve opening (Pmin) (>=0). Typical Value = 0.
t4
Inlet piping/steam bowl time constant (T4). Typical Value = 0.3.
k1
Fraction of HP shaft power after first boiler pass (K1). Typical Value = 0.2.
k2
Fraction of LP shaft power after first boiler pass (K2). Typical Value = 0.
t5
Time constant of second boiler pass (T5). Typical Value = 5.
k3
Fraction of HP shaft power after second boiler pass (K3). Typical Value = 0.3.
k4
Fraction of LP shaft power after second boiler pass (K4). Typical Value = 0.
t6
Time constant of third boiler pass (T6). Typical Value = 0.5.
k5
Fraction of HP shaft power after third boiler pass (K5). Typical Value = 0.5.
k6
Fraction of LP shaft power after third boiler pass (K6). Typical Value = 0.
t7
Time constant of fourth boiler pass (T7). Typical Value = 0.
k7
Fraction of HP shaft power after fourth boiler pass (K7). Typical Value = 0.
k8
Fraction of LP shaft power after fourth boiler pass (K8). Typical Value = 0.
db1
Intentional deadband width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
sdb1
Intentional deadband indicator.
true = intentional deadband is applied
false = intentional deadband is not applied.
Typical Value = true.
sdb2
Unintentional deadband location.
true = intentional deadband is applied before point "A"
false = intentional deadband is applied after point "A".
Typical Value = true.
db2
Unintentional deadband (db2). Unit = MW. Typical Value = 0.
valve
Nonlinear valve characteristic.
true = nonlinear valve characteristic is used
false = nonlinear valve characteristic is not used.
Typical Value = true.
gv1
Nonlinear gain valve position point 1 (GV1). Typical Value = 0.
pgv1
Nonlinear gain power value point 1 (Pgv1). Typical Value = 0.
gv2
Nonlinear gain valve position point 2 (GV2). Typical Value = 0.4.
pgv2
Nonlinear gain power value point 2 (Pgv2). Typical Value = 0.75.
gv3
Nonlinear gain valve position point 3 (GV3). Typical Value = 0.5.
pgv3
Nonlinear gain power value point 3 (Pgv3). Typical Value = 0.91.
gv4
Nonlinear gain valve position point 4 (GV4). Typical Value = 0.6.
pgv4
Nonlinear gain power value point 4 (Pgv4). Typical Value = 0.98.
gv5
Nonlinear gain valve position point 5 (GV5). Typical Value = 1.
pgv5
Nonlinear gain power value point 5 (Pgv5). Typical Value = 1.
gv6
Nonlinear gain valve position point 6 (GV6). Typical Value = 0.
pgv6
Nonlinear gain power value point 6 (Pgv6). Typical Value = 0.
GovSteam2
Simplified governor model.
k
Governor gain (reciprocal of droop) (K). Typical Value = 20.
dbf
Frequency dead band (DBF). Typical Value = 0.
t1
Governor lag time constant (T1) (>0). Typical Value = 0.45.
t2
Governor lead time constant (T2) (may be 0). Typical Value = 0.
pmax
Maximum fuel flow (PMAX). Typical Value = 1.
pmin
Minimum fuel flow (PMIN). Typical Value = 0.
mxef
Fuel flow maximum positive error value (MXEF). Typical Value = 1.
mnef
Fuel flow maximum negative error value (MNEF). Typical Value = -1.
GovSteamCC
Cross compound turbine governor model.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
pmaxhp
Maximum HP value position (Pmaxhp). Typical Value = 1.
rhp
HP governor droop (Rhp). Typical Value = 0.05.
t1hp
HP governor time constant (T1hp). Typical Value = 0.1.
t3hp
HP turbine time constant (T3hp). Typical Value = 0.1.
t4hp
HP turbine time constant (T4hp). Typical Value = 0.1.
t5hp
HP reheater time constant (T5hp). Typical Value = 10.
fhp
Fraction of HP power ahead of reheater (Fhp). Typical Value = 0.3.
dhp
HP damping factor (Dhp). Typical Value = 0.
pmaxlp
Maximum LP value position (Pmaxlp). Typical Value = 1.
rlp
LP governor droop (Rlp). Typical Value = 0.05.
t1lp
LP governor time constant (T1lp). Typical Value = 0.1.
t3lp
LP turbine time constant (T3lp). Typical Value = 0.1.
t4lp
LP turbine time constant (T4lp). Typical Value = 0.1.
t5lp
LP reheater time constant (T5lp). Typical Value = 10.
flp
Fraction of LP power ahead of reheater (Flp). Typical Value = 0.7.
dlp
LP damping factor (Dlp). Typical Value = 0.
GovSteamEU
Simplified model of boiler and steam turbine with PID governor.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
tp
Power transducer time constant (Tp). Typical Value = 0.07.
ke
Gain of the power controller (Ke). Typical Value = 0.65.
tip
Integral time constant of the power controller (Tip). Typical Value = 2.
tdp
Derivative time constant of the power controller (Tdp). Typical Value = 0.
tfp
Time constant of the power controller (Tfp). Typical Value = 0.
tf
Frequency transducer time constant (Tf). Typical Value = 0.
kfcor
Gain of the frequency corrector (Kfcor). Typical Value = 20.
db1
Dead band of the frequency corrector (db1). Typical Value = 0.
wfmax
Upper limit for frequency correction (Wfmax). Typical Value = 0.05.
wfmin
Lower limit for frequency correction (Wfmin). Typical Value = -0.05.
pmax
Maximal active power of the turbine (Pmax). Typical Value = 1.
ten
Electro hydraulic transducer (Ten). Typical Value = 0.1.
tw
Speed transducer time constant (Tw). Typical Value = 0.02.
kwcor
Gain of the speed governor (Kwcor). Typical Value = 20.
db2
Dead band of the speed governor (db2). Typical Value = 0.0004.
wwmax
Upper limit for the speed governor (Wwmax). Typical Value = 0.1.
wwmin
Lower limit for the speed governor frequency correction (Wwmin). Typical Value = -1.
wmax1
Emergency speed control lower limit (wmax1). Typical Value = 1.025.
wmax2
Emergency speed control upper limit (wmax2). Typical Value = 1.05.
tvhp
Control valves servo time constant (Tvhp). Typical Value = 0.1.
cho
Control valves rate opening limit (Cho). Unit = PU/sec. Typical Value = 0.17.
chc
Control valves rate closing limit (Chc). Unit = PU/sec. Typical Value = -3.3.
hhpmax
Maximum control valve position (Hhpmax). Typical Value = 1.
tvip
Intercept valves servo time constant (Tvip). Typical Value = 0.15.
cio
Intercept valves rate opening limit (Cio). Typical Value = 0.123.
cic
Intercept valves rate closing limit (Cic). Typical Value = -2.2.
simx
Intercept valves transfer limit (Simx). Typical Value = 0.425.
thp
High pressure (HP) time constant of the turbine (Thp). Typical Value = 0.31.
trh
Reheater time constant of the turbine (Trh). Typical Value = 8.
tlp
Low pressure(LP) time constant of the turbine (Tlp). Typical Value = 0.45.
prhmax
Maximum low pressure limit (Prhmax). Typical Value = 1.4.
khp
Fraction of total turbine output generated by HP part (Khp). Typical Value = 0.277.
klp
Fraction of total turbine output generated by HP part (Klp). Typical Value = 0.723.
tb
Boiler time constant (Tb). Typical Value = 100.
GovSteamFV2
Steam turbine governor with reheat time constants and modeling of the effects of fast valve closing to reduce mechanical power.
mwbase
Alternate Base used instead of Machine base in equipment model if necessary (MWbase) (>0). Unit = MW.
r
(R).
t1
Governor time constant (T1).
vmax
(Vmax).
vmin
(Vmin).
k
Fraction of the turbine power developed by turbine sections not involved in fast valving (K).
t3
Reheater time constant (T3).
dt
(Dt).
tt
Time constant with which power falls off after intercept valve closure (Tt).
ta
Time after initial time for valve to close (Ta).
tb
Time after initial time for valve to begin opening (Tb).
tc
Time after initial time for valve to become fully open (Tc).
ti
Initial time to begin fast valving (Ti).
GovSteamFV3
Simplified GovSteamIEEE1 Steam turbine governor model with Prmax limit and fast valving.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
k
Governor gain, (reciprocal of droop) (K). Typical Value = 20.
t1
Governor lead time constant (T1). Typical Value = 0.
t2
Governor lag time constant (T2). Typical Value = 0.
t3
Valve positioner time constant (T3). Typical Value = 0.
uo
Maximum valve opening velocity (Uo). Unit = PU/sec. Typical Value = 0.1.
uc
Maximum valve closing velocity (Uc). Unit = PU/sec. Typical Value = -1.
pmax
Maximum valve opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum valve opening, PU of MWbase (Pmin). Typical Value = 0.
t4
Inlet piping/steam bowl time constant (T4). Typical Value = 0.2.
k1
Fraction of turbine power developed after first boiler pass (K1). Typical Value = 0.2.
t5
Time constant of second boiler pass (i.e. reheater) (T5). Typical Value = 0.5.
k2
Fraction of turbine power developed after second boiler pass (K2). Typical Value = 0.2.
t6
Time constant of crossover or third boiler pass (T6). Typical Value = 10.
k3
Fraction of hp turbine power developed after crossover or third boiler pass (K3). Typical Value = 0.6.
ta
Time to close intercept valve (IV) (Ta). Typical Value = 0.97.
tb
Time until IV starts to reopen (Tb). Typical Value = 0.98.
tc
Time until IV is fully open (Tc). Typical Value = 0.99.
prmax
Max. pressure in reheater (Prmax). Typical Value = 1.
GovSteamFV4
Detailed electro-hydraulic governor for steam unit.
kf1
Frequency bias (reciprocal of droop) (Kf1). Typical Value = 20.
kf3
Frequency control (reciprocal of droop) (Kf3). Typical Value = 20.
lps
Maximum positive power error (Lps). Typical Value = 0.03.
lpi
Maximum negative power error (Lpi). Typical Value = -0.15.
mxef
Upper limit for frequency correction (MXEF). Typical Value = 0.05.
mnef
Lower limit for frequency correction (MNEF). Typical Value = -0.05.
crmx
Maximum value of regulator set-point (Crmx). Typical Value = 1.2.
crmn
Minimum value of regulator set-point (Crmn). Typical Value = 0.
kpt
Proportional gain of electro-hydraulic regulator (Kpt). Typical Value = 0.3.
kit
Integral gain of electro-hydraulic regulator (Kit). Typical Value = 0.04.
rvgmx
Maximum value of integral regulator (Rvgmx). Typical Value = 1.2.
rvgmn
Minimum value of integral regulator (Rvgmn). Typical Value = 0.
svmx
Maximum regulator gate opening velocity (Svmx). Typical Value = 0.0333.
svmn
Maximum regulator gate closing velocity (Svmn). Typical Value = -0.0333.
srmx
Maximum valve opening (Srmx). Typical Value = 1.1.
srmn
Minimum valve opening (Srmn). Typical Value = 0.
kpp
Proportional gain of pressure feedback regulator (Kpp). Typical Value = 1.
kip
Integral gain of pressure feedback regulator (Kip). Typical Value = 0.5.
rsmimx
Maximum value of integral regulator (Rsmimx). Typical Value = 1.1.
rsmimn
Minimum value of integral regulator (Rsmimn). Typical Value = 0.
kmp1
First gain coefficient of intercept valves characteristic (Kmp1). Typical Value = 0.5.
kmp2
Second gain coefficient of intercept valves characteristic (Kmp2). Typical Value = 3.5.
srsmp
Intercept valves characteristic discontinuity point (Srsmp). Typical Value = 0.43.
ta
Control valves rate opening time (Ta). Typical Value = 0.8.
tc
Control valves rate closing time (Tc). Typical Value = 0.5.
ty
Control valves servo time constant (Ty). Typical Value = 0.1.
yhpmx
Maximum control valve position (Yhpmx). Typical Value = 1.1.
yhpmn
Minimum control valve position (Yhpmn). Typical Value = 0.
tam
Intercept valves rate opening time (Tam). Typical Value = 0.8.
tcm
Intercept valves rate closing time (Tcm). Typical Value = 0.5.
ympmx
Maximum intercept valve position (Ympmx). Typical Value = 1.1.
ympmn
Minimum intercept valve position (Ympmn). Typical Value = 0.
y
Coefficient of linearized equations of turbine (Stodola formulation) (Y). Typical Value = 0.13.
thp
High pressure (HP) time constant of the turbine (Thp). Typical Value = 0.15.
trh
Reheater time constant of the turbine (Trh). Typical Value = 10.
tmp
Low pressure (LP) time constant of the turbine (Tmp). Typical Value = 0.4.
khp
Fraction of total turbine output generated by HP part (Khp). Typical Value = 0.35.
pr1
First value of pressure set point static characteristic (Pr1). Typical Value = 0.2.
pr2
Second value of pressure set point static characteristic, corresponding to Ps0 = 1.0 PU (Pr2). Typical Value = 0.75.
psmn
Minimum value of pressure set point static characteristic (Psmn). Typical Value = 1.
kpc
Proportional gain of pressure regulator (Kpc). Typical Value = 0.5.
kic
Integral gain of pressure regulator (Kic). Typical Value = 0.0033.
kdc
Derivative gain of pressure regulator (Kdc). Typical Value = 1.
tdc
Derivative time constant of pressure regulator (Tdc). Typical Value = 90.
cpsmx
Maximum value of pressure regulator output (Cpsmx). Typical Value = 1.
cpsmn
Minimum value of pressure regulator output (Cpsmn). Typical Value = -1.
krc
Maximum variation of fuel flow (Krc). Typical Value = 0.05.
tf1
Time constant of fuel regulation (Tf1). Typical Value = 10.
tf2
Time constant of steam chest (Tf2). Typical Value = 10.
tv
Boiler time constant (Tv). Typical Value = 60.
ksh
Pressure loss due to flow friction in the boiler tubes (Ksh). Typical Value = 0.08.
GovSteamSGO
Simplified Steam turbine governor model.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
t1
Controller lag (T1).
t2
Controller lead compensation (T2).
t3
Governor lag (T3) (>0).
t4
Delay due to steam inlet volumes associated with steam chest and inlet piping (T4).
t5
Reheater delay including hot and cold leads (T5).
t6
Delay due to IP-LP turbine, crossover pipes and LP end hoods (T6).
k1
One/per unit regulation (K1).
k2
Fraction (K2).
k3
Fraction (K3).
pmax
Upper power limit (Pmax).
pmin
Lower power limit (Pmin).
TurbineLoadControllerDynamics
A turbine load controller acts to maintain turbine power at a set value by continuous adjustment of the turbine governor speed-load reference.
TurbineLoadControllerDynamics
Turbine load controller function block whose behavior is described by reference to a standard model or by definition of a user-defined model.
abstract
TurbLCFB1
Turbine Load Controller model developed in the WECC. This model represents a supervisory turbine load controller that acts to maintain turbine power at a set value by continuous adjustment of the turbine governor speed-load reference. This model is intended to represent slow reset 'outer loop' controllers managing the action of the turbine governor.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
speedReferenceGovernor
Type of turbine governor reference (Type).
true = speed reference governor
false = load reference governor.
Typical Value = true.
db
Controller dead band (db). Typical Value = 0.
emax
Maximum control error (Emax) (note 4). Typical Value = 0.02.
fb
Frequency bias gain (Fb). Typical Value = 0.
kp
Proportional gain (Kp). Typical Value = 0.
ki
Integral gain (Ki). Typical Value = 0.
fbf
Frequency bias flag (Fbf).
true = enable frequency bias
false = disable frequency bias.
Typical Value = false.
pbf
Power controller flag (Pbf).
true = enable load controller
false = disable load controller.
Typical Value = false.
tpelec
Power transducer time constant (Tpelec). Typical Value = 0.
irmax
Maximum turbine speed/load reference bias (Irmax) (note 3). Typical Value = 0.
pmwset
Power controller setpoint (Pmwset) (note 1). Unit = MW. Typical Value = 0.
MechanicalLoadDynamics
A mechanical load represents the variation in a motor's shaft torque or power as a function of shaft speed.
MechanicalLoadDynamics
Mechanical load function block whose behavior is described by reference to a standard model or by definition of a user-defined model.
abstract
MechLoad1
Mechanical load model type 1.
a
Speed squared coefficient (a).
b
Speed coefficient (b).
d
Speed to the exponent coefficient (d).
e
Exponent (e).
ExcitationSystemDynamics
The excitation system model provides the field voltage (Efd) for a synchronous machine model. It is linked to a specific generator (synchronous machine). The data parameters are different for each excitation system model; the same parameter name may have different meaning in different models.
ExcIEEEST1AUELselectorKind
Type of connection for the UEL input used in ExcIEEEST1A.
ignoreUELsignal
Ignore UEL signal.
inputHVgateVoltageOutput
UEL input HV gate with voltage regulator output.
inputHVgateErrorSignal
UEL input HV gate with error signal.
inputAddedToErrorSignal
UEL input added to error signal.
ExcREXSFeedbackSignalKind
Type of rate feedback signals.
fieldVoltage
The voltage regulator output voltage is used. It is the same as exciter field voltage.
fieldCurrent
The exciter field current is used.
outputVoltage
The output voltage of the exciter is used.
ExcST6BOELselectorKind
Type of connection for the OEL input used for static excitation systems type 6B.
noOELinput
No OEL input is used.
beforeUEL
The connection is before UEL.
afterUEL
The connection is after UEL.
ExcST7BOELselectorKind
Type of connection for the OEL input used for static excitation systems type 7B.
noOELinput
No OEL input is used.
addVref
The signal is added to Vref.
inputLVgate
The signal is connected in the input of the LV gate.
outputLVgate
The signal is connected in the output of the LV gate.
ExcST7BUELselectorKind
Type of connection for the UEL input used for static excitation systems type 7B.
noUELinput
No UEL input is used.
addVref
The signal is added to Vref.
inputHVgate
The signal is connected in the input of the HV gate.
outputHVgate
The signal is connected in the output of the HV gate.
ExcitationSystemDynamics
Excitation system function block whose behavior is described by reference to a standard model or by definition of a user-defined model.
abstract
ExcitationSystemDynamics
Excitation system model with which this power system stabilizer model is associated.
Yes
PowerSystemStabilizerDynamics
Power system stabilizer model associated with this excitation system model.
PowerSystemStabilizerDynamics
No
ExcitationSystemDynamics
Excitation system model with which this Power Factor or VAr controller Type I model is associated.
Yes
PFVArControllerType1Dynamics
Power Factor or VAr controller Type I model associated with this excitation system model.
PFVArControllerType1Dynamics
No
ExcitationSystemDynamics
Excitation system model with which this voltage compensator is associated.
Yes
VoltageCompensatorDynamics
Voltage compensator model associated with this excitation system model.
VoltageCompensatorDynamics
No
ExcitationSystemDynamics
Excitation system model with which this discontinuous excitation control model is associated.
Yes
DiscontinuousExcitationControlDynamics
Discontinuous excitation control model associated with this excitation system model.
DiscontinuousExcitationControlDynamics
No
ExcitationSystemDynamics
Excitation system model with which this underexcitation limiter model is associated.
Yes
UnderexcitationLimiterDynamics
Undrexcitation limiter model associated with this excitation system model.
UnderexcitationLimiterDynamics
No
ExcitationSystemDynamics
Excitation system model with which this Power Factor or VAr controller Type II is associated.
Yes
PFVArControllerType2Dynamics
Power Factor or VAr controller Type II model associated with this excitation system model.
PFVArControllerType2Dynamics
No
ExcitationSystemDynamics
Excitation system model with which this overexcitation limiter model is associated.
Yes
OverexcitationLimiterDynamics
Overexcitation limiter model associated with this excitation system model.
OverexcitationLimiterDynamics
No
ExcIEEEAC1A
The class represents IEEE Std 421.5-2005 type AC1A model. The model represents the field-controlled alternator-rectifier excitation systems designated Type AC1A. These excitation systems consist of an alternator main exciter with non-controlled rectifiers.
Reference: IEEE Standard 421.5-2005 Section 6.1.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 400.
ta
Voltage regulator time constant (TA). Typical Value = 0.02.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 14.5.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -14.5.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.8.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.03.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.2.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 0.38.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1). Typical Value = 4.18.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.1.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 3.14.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.03.
vrmax
Maximum voltage regulator outputs (VRMAX). Typical Value = 6.03.
vrmin
Minimum voltage regulator outputs (VRMIN). Typical Value = -5.43.
ExcIEEEAC2A
The class represents IEEE Std 421.5-2005 type AC2A model. The model represents a high initial response field-controlled alternator-rectifier excitation system. The alternator main exciter is used with non-controlled rectifiers. The Type AC2A model is similar to that of Type AC1A except for the inclusion of exciter time constant compensation and exciter field current limiting elements.
Reference: IEEE Standard 421.5-2005 Section 6.2.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 400.
ta
Voltage regulator time constant (TA). Typical Value = 0.02.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 8.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -8.
kb
Second stage regulator gain (KB). Typical Value = 25.
vrmax
Maximum voltage regulator outputs (VRMAX). Typical Value = 105.
vrmin
Minimum voltage regulator outputs (VRMIN). Typical Value = -95.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.6.
vfemax
Exciter field current limit reference (VFEMAX). Typical Value = 4.4.
kh
Exciter field current feedback gain (KH). Typical Value = 1.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.03.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.28.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 0.35.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1). Typical Value = 4.4.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.037.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 3.3.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.012.
ExcIEEEAC3A
The class represents IEEE Std 421.5-2005 type AC3A model. The model represents the field-controlled alternator-rectifier excitation systems designated Type AC3A. These excitation systems include an alternator main exciter with non-controlled rectifiers. The exciter employs self-excitation, and the voltage regulator power is derived from the exciter output voltage. Therefore, this system has an additional nonlinearity, simulated by the use of a multiplier
whose inputs are the voltage regulator command signal, Va, and the exciter output voltage, Efd, times KR. This model is applicable to excitation systems employing static voltage regulators.
Reference: IEEE Standard 421.5-2005 Section 6.3.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 45.62.
ta
Voltage regulator time constant (TA). Typical Value = 0.013.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 1.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -0.95.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.17.
vemin
Minimum exciter voltage output (VEMIN). Typical Value = 0.1.
kr
Constant associated with regulator and alternator field power supply (KR). Typical Value = 3.77.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.143.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
kn
Excitation control system stabilizer gain (KN). Typical Value = 0.05.
efdn
Value of EFD at which feedback gain changes (EFDN). Typical Value = 2.36.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.104.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 0.499.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
vfemax
Exciter field current limit reference (VFEMAX). Typical Value = 16.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1) equals VEMAX (VE1). Typical Value = 6.24.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 1.143.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 4.68.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.1.
ExcIEEEAC4A
The class represents IEEE Std 421.5-2005 type AC4A model. The model represents type AC4A alternator-supplied controlled-rectifier excitation system which is quite different from the other type ac systems. This high initial response excitation system utilizes a full thyristor bridge in the exciter output circuit. The voltage regulator controls the firing of the thyristor bridges. The exciter alternator uses an independent voltage regulator to control its output voltage to a constant value. These effects are not modeled; however, transient loading effects on the exciter alternator are included.
Reference: IEEE Standard 421.5-2005 Section 6.4.
vimax
Maximum voltage regulator input limit (VIMAX). Typical Value = 10.
vimin
Minimum voltage regulator input limit (VIMIN). Typical Value = -10.
tc
Voltage regulator time constant (TC). Typical Value = 1.
tb
Voltage regulator time constant (TB). Typical Value = 10.
ka
Voltage regulator gain (KA). Typical Value = 200.
ta
Voltage regulator time constant (TA). Typical Value = 0.015.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 5.64.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -4.53.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.
ExcIEEEAC5A
The class represents IEEE Std 421.5-2005 type AC5A model. The model represents a simplified model for brushless excitation systems. The regulator is supplied from a source, such as a permanent magnet generator, which is not affected by system disturbances. Unlike other ac models, this model uses loaded rather than open circuit exciter saturation data in the same way as it is used for the dc models. Because the model has been widely implemented by the industry, it is sometimes used to represent other types of systems when either detailed data for them are not available or simplified models are required.
Reference: IEEE Standard 421.5-2005 Section 6.5.
ka
Voltage regulator gain (KA). Typical Value = 400.
ta
Voltage regulator time constant (TA). Typical Value = 0.02.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 7.3.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -7.3.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.8.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.03.
tf1
Excitation control system stabilizer time constant (TF1). Typical Value = 1.
tf2
Excitation control system stabilizer time constant (TF2). Typical Value = 1.
tf3
Excitation control system stabilizer time constant (TF3). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 5.6.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.86.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 4.2.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.5.
ExcIEEEAC6A
The class represents IEEE Std 421.5-2005 type AC6A model. The model represents field-controlled alternator-rectifier excitation systems with system-supplied electronic voltage regulators. The maximum output of the regulator, VR, is a function of terminal voltage, VT. The field current limiter included in the original model AC6A remains in the 2005 update.
Reference: IEEE Standard 421.5-2005 Section 6.6.
ka
Voltage regulator gain (KA). Typical Value = 536.
ta
Voltage regulator time constant (TA). Typical Value = 0.086.
tk
Voltage regulator time constant (TK). Typical Value = 0.18.
tb
Voltage regulator time constant (TB). Typical Value = 9.
tc
Voltage regulator time constant (TC). Typical Value = 3.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 75.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -75.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 44.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -36.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.
kh
Exciter field current limiter gain (KH). Typical Value = 92.
tj
Exciter field current limiter time constant (TJ). Typical Value = 0.02.
th
Exciter field current limiter time constant (TH). Typical Value = 0.08.
vfelim
Exciter field current limit reference (VFELIM). Typical Value = 19.
vhmax
Maximum field current limiter signal reference (VHMAX). Typical Value = 75.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.173.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 1.91.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.6.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1) equals VEMAX (VE1). Typical Value = 7.4.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.214.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 5.55.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.044.
ExcIEEEAC7B
The class represents IEEE Std 421.5-2005 type AC7B model. The model represents excitation systems which consist of an ac alternator with either stationary or rotating rectifiers to produce the dc field requirements. It is an upgrade to earlier ac excitation systems, which replace only the controls but retain the ac alternator and diode rectifier bridge.
Reference: IEEE Standard 421.5-2005 Section 6.7.
Note: In the IEEE Standard 421.5 – 2005, the [1 / sTE] block is shown as [1 / (1 + sTE)], which is incorrect.
kpr
Voltage regulator proportional gain (KPR). Typical Value = 4.24.
kir
Voltage regulator integral gain (KIR). Typical Value = 4.24.
kdr
Voltage regulator derivative gain (KDR). Typical Value = 0.
tdr
Lag time constant (TDR). Typical Value = 0.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 5.79.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -5.79.
kpa
Voltage regulator proportional gain (KPA). Typical Value = 65.36.
kia
Voltage regulator integral gain (KIA). Typical Value = 59.69.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 1.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -0.95.
kp
Potential circuit gain coefficient (KP). Typical Value = 4.96.
kl
Exciter field voltage lower limit parameter (KL). Typical Value = 10.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.1.
vfemax
Exciter field current limit reference (VFEMAX). Typical Value = 6.9.
vemin
Minimum exciter voltage output (VEMIN). Typical Value = 0.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.18.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 0.02.
kf1
Excitation control system stabilizer gain (KF1). Typical Value = 0.212.
kf2
Excitation control system stabilizer gain (KF2). Typical Value = 0.
kf3
Excitation control system stabilizer gain (KF3). Typical Value = 0.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1) equals VEMAX (VE1). Typical Value = 6.3.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.44.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 3.02.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.075.
ExcIEEEAC8B
The class represents IEEE Std 421.5-2005 type AC8B model. This model represents a PID voltage regulator with either a brushless exciter or dc exciter. The AVR in this model consists of PID control, with separate constants for the proportional (KPR), integral (KIR), and derivative (KDR) gains. The representation of the brushless exciter (TE, KE, SE, KC, KD) is similar to the model Type AC2A. The Type AC8B model can be used to represent static voltage regulators applied to brushless excitation systems. Digitally based voltage regulators feeding dc rotating main exciters can be represented with the AC Type AC8B model with the parameters KC and KD set to 0. For thyristor power stages fed from the generator terminals, the limits VRMAX and VRMIN should be a function of terminal voltage: VT * VRMAX and VT * VRMIN.
Reference: IEEE Standard 421.5-2005 Section 6.8.
kpr
Voltage regulator proportional gain (KPR). Typical Value = 80.
kir
Voltage regulator integral gain (KIR). Typical Value = 5.
kdr
Voltage regulator derivative gain (KDR). Typical Value = 10.
tdr
Lag time constant (TDR). Typical Value = 0.1.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 35.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 1.
ta
Voltage regulator time constant (TA). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.2.
vfemax
Exciter field current limit reference (VFEMAX). Typical Value = 6.
vemin
Minimum exciter voltage output (VEMIN). Typical Value = 0.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.55.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 1.1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1) equals VEMAX (VE1). Typical Value = 6.5.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.3.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 9.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 3.
ExcIEEEDC1A
The class represents IEEE Std 421.5-2005 type DC1A model. This model represents field-controlled dc commutator exciters with continuously acting voltage regulators (especially the direct-acting rheostatic, rotating amplifier, and magnetic amplifier types). Because this model has been widely implemented by the industry, it is sometimes used to represent other types of systems when detailed data for them are not available or when a simplified model is required.
Reference: IEEE Standard 421.5-2005 Section 5.1.
ka
Voltage regulator gain (KA). Typical Value = 46.
ta
Voltage regulator time constant (TA). Typical Value = 0.06.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 1.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -0.9.
ke
Exciter constant related to self-excited field (KE). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.46.
kf
Excitation control system stabilizer gain (KF). Typical Value = 0.1.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 3.1.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.33.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 2.3.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.1.
uelin
UEL input (uelin).
true = input is connected to the HV gate
false = input connects to the error signal.
Typical Value = true.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero is not applied to integrator output.
Typical Value = true.
ExcIEEEDC2A
The class represents IEEE Std 421.5-2005 type DC2A model. This model represents represent field-controlled dc commutator exciters with continuously acting voltage regulators having supplies obtained from the generator or auxiliary bus. It differs from the Type DC1A model only in the voltage regulator output limits, which are now proportional to terminal voltage VT.
It is representative of solid-state replacements for various forms of older mechanical and rotating amplifier regulating equipment connected to dc commutator exciters.
Reference: IEEE Standard 421.5-2005 Section 5.2.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 3.05.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 2.29.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output. Typical Value = - 999 which means that there is no limit applied.
ka
Voltage regulator gain (KA). Typical Value = 300.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
kf
Excitation control system stabilizer gain (KF). Typical Value = 0.1.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.279.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.117.
ta
Voltage regulator time constant (TA). Typical Value = 0.01.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.33.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 0.675.
uelin
UEL input (uelin).
true = input is connected to the HV gate
false = input connects to the error signal.
Typical Value = true.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 4.95.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -4.9.
ExcIEEEDC3A
The class represents IEEE Std 421.5-2005 type DC3A model. This model represents represent older systems, in particular those dc commutator exciters with non-continuously acting regulators that were commonly used before the development of the continuously acting varieties. These systems respond at basically two different rates, depending upon the magnitude of voltage error. For small errors, adjustment is made periodically with a signal to a motor-operated rheostat. Larger errors cause resistors to be quickly shorted or inserted and a strong forcing signal applied to the exciter. Continuous motion of the motor-operated rheostat occurs for these larger error signals, even though it is bypassed by contactor action.
Reference: IEEE Standard 421.5-2005 Section 5.3.
trh
Rheostat travel time (TRH). Typical Value = 20.
kv
Fast raise/lower contact setting (KV). Typical Value = 0.05.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 1.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.5.
ke
Exciter constant related to self-excited field (KE). Typical Value = 0.05.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 3.375.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.267.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 3.15.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.068.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero is not applied to integrator output.
Typical Value = true.
ExcIEEEDC4B
The class represents IEEE Std 421.5-2005 type DC4B model. These excitation systems utilize a field-controlled dc commutator exciter with a continuously acting voltage regulator having supplies obtained from the generator or auxiliary bus.
Reference: IEEE Standard 421.5-2005 Section 5.4.
ka
Voltage regulator gain (KA). Typical Value = 1.
ta
Voltage regulator time constant (TA). Typical Value = 0.2.
kp
Regulator proportional gain (KP). Typical Value = 20.
ki
Regulator integral gain (KI). Typical Value = 20.
kd
Regulator derivative gain (KD). Typical Value = 20.
td
Regulator derivative filter time constant(TD). Typical Value = 0.01.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 2.7.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -0.9.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.8.
kf
Excitation control system stabilizer gain (KF). Typical Value = 0.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 1.75.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.08.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 2.33.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.27.
vemin
Minimum exciter voltage output(VEMIN). Typical Value = 0.
oelin
OEL input (OELin).
true = LV gate
false = subtract from error signal.
Typical Value = true.
uelin
UEL input (UELin).
true = HV gate
false = add to error signal.
Typical Value = true.
ExcIEEEST1A
The class represents IEEE Std 421.5-2005 type ST1A model. This model represents systems in which excitation power is supplied through a transformer from the generator terminals (or the unit’s auxiliary bus) and is regulated by a controlled rectifier. The maximum exciter voltage available from such systems is directly related to the generator terminal voltage.
Reference: IEEE Standard 421.5-2005 Section 7.1.
ilr
Exciter output current limit reference (ILR). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 190.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.08.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.
klr
Exciter output current limiter gain (KLR). Typical Value = 0.
pssin
Selector of the Power System Stabilizer (PSS) input (PSSin).
true = PSS input (Vs) added to error signal
false = PSS input (Vs) added to voltage regulator output.
Typical Value = true.
ta
Voltage regulator time constant (TA). Typical Value = 0.
tb
Voltage regulator time constant (TB). Typical Value = 10.
tb1
Voltage regulator time constant (TB1). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 1.
tc1
Voltage regulator time constant (TC1). Typical Value = 0.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
uelin
Selector of the connection of the UEL input (UELin). Typical Value = ignoreUELsignal.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 14.5.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -14.5.
vimax
Maximum voltage regulator input limit (VIMAX). Typical Value = 999.
vimin
Minimum voltage regulator input limit (VIMIN). Typical Value = -999.
vrmax
Maximum voltage regulator outputs (VRMAX). Typical Value = 7.8.
vrmin
Minimum voltage regulator outputs (VRMIN). Typical Value = -6.7.
ExcIEEEST2A
The class represents IEEE Std 421.5-2005 type ST2A model. Some static systems utilize both current and voltage sources (generator terminal quantities) to comprise the power source. The regulator controls the exciter output through controlled saturation of the power transformer components. These compound-source rectifier excitation systems are designated Type ST2A and are represented by ExcIEEEST2A.
Reference: IEEE Standard 421.5-2005 Section 7.2.
ka
Voltage regulator gain (KA). Typical Value = 120.
ta
Voltage regulator time constant (TA). Typical Value = 0.15.
vrmax
Maximum voltage regulator outputs (VRMAX). Typical Value = 1.
vrmin
Minimum voltage regulator outputs (VRMIN). Typical Value = 0.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.5.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.05.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
kp
Potential circuit gain coefficient (KP). Typical Value = 4.88.
ki
Potential circuit gain coefficient (KI). Typical Value = 8.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 1.82.
efdmax
Maximum field voltage (EFDMax). Typical Value = 99.
uelin
UEL input (UELin).
true = HV gate
false = add to error signal.
Typical Value = true.
ExcIEEEST3A
The class represents IEEE Std 421.5-2005 type ST3A model. Some static systems utilize a field voltage control loop to linearize the exciter control characteristic. This also makes the output independent of supply source variations until supply limitations are reached. These systems utilize a variety of controlled-rectifier designs: full thyristor complements or hybrid bridges
in either series or shunt configurations. The power source may consist of only a potential source, either fed from the machine terminals or from internal windings. Some designs may have compound power sources utilizing both machine potential and current. These power sources are represented as phasor combinations of machine terminal current and voltage and are accommodated by suitable parameters in model Type ST3A which is represented by ExcIEEEST3A.
Reference: IEEE Standard 421.5-2005 Section 7.3.
vimax
Maximum voltage regulator input limit (VIMAX). Typical Value = 0.2.
vimin
Minimum voltage regulator input limit (VIMIN). Typical Value = -0.2.
ka
Voltage regulator gain (KA). This is parameter K in the IEEE Std. Typical Value = 200.
ta
Voltage regulator time constant (TA). Typical Value = 0.
tb
Voltage regulator time constant (TB). Typical Value = 10.
tc
Voltage regulator time constant (TC). Typical Value = 1.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 10.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -10.
km
Forward gain constant of the inner loop field regulator (KM). Typical Value = 7.93.
tm
Forward time constant of inner loop field regulator (TM). Typical Value = 0.4.
vmmax
Maximum inner loop output (VMMax). Typical Value = 1.
vmmin
Minimum inner loop output (VMMin). Typical Value = 0.
kg
Feedback gain constant of the inner loop field regulator (KG). Typical Value = 1.
kp
Potential circuit gain coefficient (KP). Typical Value = 6.15.
thetap
Potential circuit phase angle (thetap). Typical Value = 0.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
multiplier
ki
Potential circuit gain coefficient (KI). Typical Value = 0.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.2.
xl
Reactance associated with potential source (XL). Typical Value = 0.081.
vbmax
Maximum excitation voltage (VBMax). Typical Value = 6.9.
vgmax
Maximum inner loop feedback voltage (VGMax). Typical Value = 5.8.
ExcIEEEST4B
The class represents IEEE Std 421.5-2005 type ST4B model. This model is a variation of the Type ST3A model, with a proportional plus integral (PI) regulator block replacing the lag-lead regulator characteristic that is in the ST3A model. Both potential and compound source rectifier excitation systems are modeled. The PI regulator blocks have non-windup limits that are represented. The voltage regulator of this model is typically implemented digitally.
Reference: IEEE Standard 421.5-2005 Section 7.4.
kpr
Voltage regulator proportional gain (KPR). Typical Value = 10.75.
kir
Voltage regulator integral gain (KIR). Typical Value = 10.75.
ta
Voltage regulator time constant (TA). Typical Value = 0.02.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 1.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -0.87.
kpm
Voltage regulator proportional gain output (KPM). Typical Value = 1.
kim
Voltage regulator integral gain output (KIM). Typical Value = 0.
vmmax
Maximum inner loop output (VMMax). Typical Value = 99.
vmmin
Minimum inner loop output (VMMin). Typical Value = -99.
kg
Feedback gain constant of the inner loop field regulator (KG). Typical Value = 0.
kp
Potential circuit gain coefficient (KP). Typical Value = 9.3.
thetap
Potential circuit phase angle (thetap). Typical Value = 0.
ki
Potential circuit gain coefficient (KI). Typical Value = 0.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.113.
xl
Reactance associated with potential source (XL). Typical Value = 0.124.
vbmax
Maximum excitation voltage (VBMax). Typical Value = 11.63.
ExcIEEEST5B
The class represents IEEE Std 421.5-2005 type ST5B model. The Type ST5B excitation system is a variation of the Type ST1A model, with alternative overexcitation and underexcitation inputs and additional limits.
Reference: IEEE Standard 421.5-2005 Section 7.5.
Note: the block diagram in the IEEE 421.5 standard has input signal Vc and does not indicate the summation point with Vref. The implementation of the ExcIEEEST5B shall consider summation point with Vref.
kr
Regulator gain (KR). Typical Value = 200.
t1
Firing circuit time constant (T1). Typical Value = 0.004.
kc
Rectifier regulation factor (KC). Typical Value = 0.004.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 5.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -4.
tc1
Regulator lead time constant (TC1). Typical Value = 0.8.
tb1
Regulator lag time constant (TB1). Typical Value = 6.
tc2
Regulator lead time constant (TC2). Typical Value = 0.08.
tb2
Regulator lag time constant (TB2). Typical Value = 0.01.
toc1
OEL lead time constant (TOC1). Typical Value = 0.1.
tob1
OEL lag time constant (TOB1). Typical Value = 2.
toc2
OEL lead time constant (TOC2). Typical Value = 0.08.
tob2
OEL lag time constant (TOB2). Typical Value = 0.08.
tuc1
UEL lead time constant (TUC1). Typical Value = 2.
tub1
UEL lag time constant (TUB1). Typical Value = 10.
tuc2
UEL lead time constant (TUC2). Typical Value = 0.1.
tub2
UEL lag time constant (TUB2). Typical Value = 0.05.
ExcIEEEST6B
The class represents IEEE Std 421.5-2005 type ST6B model. This model consists of a PI voltage regulator with an inner loop field voltage regulator and pre-control. The field voltage regulator implements a proportional control. The pre-control and the delay in the feedback circuit increase the dynamic response.
Reference: IEEE Standard 421.5-2005 Section 7.6.
ilr
Exciter output current limit reference (ILR). Typical Value = 4.164.
kci
Exciter output current limit adjustment (KCI). Typical Value = 1.0577.
kff
Pre-control gain constant of the inner loop field regulator (KFF). Typical Value = 1.
kg
Feedback gain constant of the inner loop field regulator (KG). Typical Value = 1.
kia
Voltage regulator integral gain (KIA). Typical Value = 45.094.
klr
Exciter output current limiter gain (KLR). Typical Value = 17.33.
km
Forward gain constant of the inner loop field regulator (KM). Typical Value = 1.
kpa
Voltage regulator proportional gain (KPA). Typical Value = 18.038.
oelin
OEL input selector (OELin). Typical Value = noOELinput.
tg
Feedback time constant of inner loop field voltage regulator (TG). Typical Value = 0.02.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 4.81.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -3.85.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 4.81.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -3.85.
ExcIEEEST7B
The class represents IEEE Std 421.5-2005 type ST7B model. This model is representative of static potential-source excitation systems. In this system, the AVR consists of a PI voltage regulator. A phase lead-lag filter in series allows introduction of a derivative function, typically used with brushless excitation systems. In that case, the regulator is of the PID type. In addition, the terminal voltage channel includes a phase lead-lag filter. The AVR includes the appropriate inputs on its reference for overexcitation limiter (OEL1), underexcitation limiter (UEL), stator current limiter (SCL), and current compensator (DROOP). All these limitations, when they work at voltage reference level, keep the PSS (VS signal from Type PSS1A, PSS2A, or PSS2B) in operation. However, the UEL limitation can also be transferred to the high value (HV) gate acting on the output signal. In addition, the output signal passes through a low value (LV) gate for a ceiling overexcitation limiter (OEL2).
Reference: IEEE Standard 421.5-2005 Section 7.7.
kh
High-value gate feedback gain (KH). Typical Value 1.
kia
Voltage regulator integral gain (KIA). Typical Value = 1.
kl
Low-value gate feedback gain (KL). Typical Value 1.
kpa
Voltage regulator proportional gain (KPA). Typical Value = 40.
oelin
OEL input selector (OELin). Typical Value = noOELinput.
tb
Regulator lag time constant (TB). Typical Value 1.
tc
Regulator lead time constant (TC). Typical Value 1.
tf
Excitation control system stabilizer time constant (TF). Typical Value 1.
tg
Feedback time constant of inner loop field voltage regulator (TG). Typical Value 1.
tia
Feedback time constant (TIA). Typical Value = 3.
uelin
UEL input selector (UELin). Typical Value = noUELinput.
vmax
Maximum voltage reference signal (VMAX). Typical Value = 1.1.
vmin
Minimum voltage reference signal (VMIN). Typical Value = 0.9.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 5.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -4.5.
ExcAC1A
Modified IEEE AC1A alternator-supplied rectifier excitation system with different rate feedback source.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ka
Voltage regulator gain (Ka). Typical Value = 400.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 14.5.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -14.5.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.8.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.03.
kf1
Coefficient to allow different usage of the model (Kf1). Typical Value = 0.
kf2
Coefficient to allow different usage of the model (Kf2). Typical Value = 1.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.2.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 0.38.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1). Typical Value = 4.18.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.1.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 3.14.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 0.03.
vrmax
Maximum voltage regulator outputs (Vrmax). Typical Value = 6.03.
vrmin
Minimum voltage regulator outputs (Rrmin). Typical Value = -5.43.
hvlvgates
Indicates if both HV gate and LV gate are active (HVLVgates).
true = gates are used
false = gates are not used.
Typical Value = true.
ExcAC2A
Modified IEEE AC2A alternator-supplied rectifier excitation system with different field current limit.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ka
Voltage regulator gain (Ka). Typical Value = 400.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 8.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -8.
kb
Second stage regulator gain (Kb) (>0). Exciter field current controller gain. Typical Value = 25.
kb1
Second stage regulator gain (Kb1). It is exciter field current controller gain used as alternative to Kb to represent a variant of the ExcAC2A model. Typical Value = 25.
vrmax
Maximum voltage regulator outputs (Vrmax). Typical Value = 105.
vrmin
Minimum voltage regulator outputs (Vrmin). Typical Value = -95.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.6.
vfemax
Exciter field current limit reference (Vfemax). Typical Value = 4.4.
kh
Exciter field current feedback gain (Kh). Typical Value = 1.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.03.
kl
Exciter field current limiter gain (Kl). Typical Value = 10.
vlr
Maximum exciter field current (Vlr). Typical Value = 4.4.
kl1
Coefficient to allow different usage of the model (Kl1). Typical Value = 1.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.28.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 0.35.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1). Typical Value = 4.4.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.037.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 3.3.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 0.012.
hvgate
Indicates if HV gate is active (HVgate).
true = gate is used
false = gate is not used.
Typical Value = true.
lvgate
Indicates if LV gate is active (LVgate).
true = gate is used
false = gate is not used.
Typical Value = true.
ExcAC3A
Modified IEEE AC3A alternator-supplied rectifier excitation system with different field current limit.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ka
Voltage regulator gain (Ka). Typical Value = 45.62.
ta
Voltage regulator time constant (Ta). Typical Value = 0.013.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 1.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -0.95.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.17.
vemin
Minimum exciter voltage output (Vemin). Typical Value = 0.1.
kr
Constant associated with regulator and alternator field power supply (Kr). Typical Value =3.77.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.143.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
kn
Excitation control system stabilizer gain (Kn). Typical Value =0.05.
efdn
Value of EFD at which feedback gain changes (Efdn). Typical Value = 2.36.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.104.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 0.499.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
klv
Gain used in the minimum field voltage limiter loop (Klv). Typical Value = 0.194.
kf1
Coefficient to allow different usage of the model (Kf1). Typical Value = 1.
kf2
Coefficient to allow different usage of the model (Kf2). Typical Value = 0.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
vfemax
Exciter field current limit reference (Vfemax). Typical Value = 16.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1) equals Vemax (Ve1). Typical Value = 6.24.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 1.143.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 4.68.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 0.1.
vlv
Field voltage used in the minimum field voltage limiter loop (Vlv). Typical Value = 0.79.
ExcAC4A
Modified IEEE AC4A alternator-supplied rectifier excitation system with different minimum controller output.
vimax
Maximum voltage regulator input limit (Vimax). Typical Value = 10.
vimin
Minimum voltage regulator input limit (Vimin). Typical Value = -10.
tc
Voltage regulator time constant (Tc). Typical Value = 1.
tb
Voltage regulator time constant (Tb). Typical Value = 10.
ka
Voltage regulator gain (Ka). Typical Value = 200.
ta
Voltage regulator time constant (Ta). Typical Value = 0.015.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 5.64.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -4.53.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.
ExcAC5A
Modified IEEE AC5A alternator-supplied rectifier excitation system with different minimum controller output.
ka
Voltage regulator gain (Ka). Typical Value = 400.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 7.3.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value =-7.3.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.8.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.03.
tf1
Excitation control system stabilizer time constant (Tf1). Typical Value = 1.
tf2
Excitation control system stabilizer time constant (Tf2). Typical Value = 0.8.
tf3
Excitation control system stabilizer time constant (Tf3). Typical Value = 0.
efd1
Exciter voltage at which exciter saturation is defined (Efd1). Typical Value = 5.6.
seefd1
Exciter saturation function value at the corresponding exciter voltage, Efd1 (SE[Efd1]). Typical Value = 0.86.
efd2
Exciter voltage at which exciter saturation is defined (Efd2). Typical Value = 4.2.
seefd2
Exciter saturation function value at the corresponding exciter voltage, Efd2 (SE[Efd2]). Typical Value = 0.5.
a
Coefficient to allow different usage of the model (a). Typical Value = 1.
ExcAC6A
Modified IEEE AC6A alternator-supplied rectifier excitation system with speed input.
ka
Voltage regulator gain (Ka). Typical Value = 536.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
ta
Voltage regulator time constant (Ta). Typical Value = 0.086.
tk
Voltage regulator time constant (Tk). Typical Value = 0.18.
tb
Voltage regulator time constant (Tb). Typical Value = 9.
tc
Voltage regulator time constant (Tc). Typical Value = 3.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 75.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -75.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 44.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -36.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.
kh
Exciter field current limiter gain (Kh). Typical Value = 92.
tj
Exciter field current limiter time constant (Tj). Typical Value = 0.02.
th
Exciter field current limiter time constant (Th). Typical Value = 0.08.
vfelim
Exciter field current limit reference (Vfelim). Typical Value = 19.
vhmax
Maximum field current limiter signal reference (Vhmax). Typical Value = 75.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.173.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 1.91.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.6.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1). Typical Value = 7.4.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.214.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 5.55.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 0.044.
ExcAC8B
Modified IEEE AC8B alternator-supplied rectifier excitation system with speed input and input limiter.
inlim
Input limiter indicator.
true = input limiter Vimax and Vimin is considered
false = input limiter Vimax and Vimin is not considered.
Typical Value = true.
ka
Voltage regulator gain (Ka). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.55.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 1.1.
kdr
Voltage regulator derivative gain (Kdr). Typical Value = 10.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
kir
Voltage regulator integral gain (Kir). Typical Value = 5.
kpr
Voltage regulator proportional gain (Kpr). Typical Value = 80.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
pidlim
PID limiter indicator.
true = input limiter Vpidmax and Vpidmin is considered
false = input limiter Vpidmax and Vpidmin is not considered.
Typical Value = true.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.3.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 3.
ta
Voltage regulator time constant (Ta). Typical Value = 0.
tdr
Lag time constant (Tdr). Typical Value = 0.1.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.2.
telim
Selector for the limiter on the block [1/sTe].
See diagram for meaning of true and false.
Typical Value = false.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1) equals VEMAX (Ve1). Typical Value = 6.5.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 9.
vemin
Minimum exciter voltage output (Vemin). Typical Value = 0.
vfemax
Exciter field current limit reference (Vfemax). Typical Value = 6.
vimax
Input signal maximum (Vimax). Typical Value = 35.
vimin
Input signal minimum (Vimin). Typical Value = -10.
vpidmax
PID maximum controller output (Vpidmax). Typical Value = 35.
vpidmin
PID minimum controller output (Vpidmin). Typical Value = -10.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 35.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = 0.
vtmult
Multiply by generator's terminal voltage indicator.
true =the limits Vrmax and Vrmin are multiplied by the generator’s terminal voltage to represent a thyristor power stage fed from the generator terminals
false = limits are not multiplied by generator's terminal voltage.
Typical Value = false.
ExcANS
Italian excitation system. It represents static field voltage or excitation current feedback excitation system.
k3
AVR gain (K3). Typical Value = 1000.
k2
Exciter gain (K2). Typical Value = 20.
kce
Ceiling factor (KCE). Typical Value = 1.
t3
Time constant (T3). Typical Value = 1.6.
t2
Time constant (T2). Typical Value = 0.05.
t1
Time constant (T1). Typical Value = 20.
blint
Governor Control Flag (BLINT).
0 = lead-lag regulator
1 = proportional integral regulator.
Typical Value = 0.
kvfif
Rate feedback signal flag (KVFIF).
0 = output voltage of the exciter
1 = exciter field current.
Typical Value = 0.
ifmn
Minimum exciter current (IFMN). Typical Value = -5.2.
ifmx
Maximum exciter current (IFMX). Typical Value = 6.5.
vrmn
Maximum AVR output (VRMN). Typical Value = -5.2.
vrmx
Minimum AVR output (VRMX). Typical Value = 6.5.
krvecc
Feedback enabling (KRVECC).
0 = Open loop control
1 = Closed loop control.
Typical Value = 1.
tb
Exciter time constant (TB). Typical Value = 0.04.
ExcAVR1
Italian excitation system corresponding to IEEE (1968) Type 1 Model. It represents exciter dynamo and electromechanical regulator.
ka
AVR gain (KA). Typical Value = 500.
vrmn
Maximum AVR output (VRMN). Typical Value = -6.
vrmx
Minimum AVR output (VRMX). Typical Value = 7.
ta
AVR time constant (TA). Typical Value = 0.2.
tb
AVR time constant (TB). Typical Value = 0.
te
Exciter time constant (TE). Typical Value = 1.
e1
Field voltage value 1 (E1). Typical Value = 4.18.
se1
Saturation factor at E1 (S(E1)). Typical Value = 0.1.
e2
Field voltage value 2 (E2). Typical Value = 3.14.
se2
Saturation factor at E2 (S(E2)). Typical Value = 0.03.
kf
Rate feedback gain (KF). Typical Value = 0.02.
tf
Rate feedback time constant (TF). Typical Value = 1.
ExcAVR2
Italian excitation system corresponding to IEEE (1968) Type 2 Model. It represents alternator and rotating diodes and electromechanic voltage regulators.
ka
AVR gain (KA). Typical Value = 500.
vrmn
Maximum AVR output (VRMN). Typical Value = -6.
vrmx
Minimum AVR output (VRMX). Typical Value = 7.
ta
AVR time constant (TA). Typical Value = 0.02.
tb
AVR time constant (TB). Typical Value = 0.
te
Exciter time constant (TE). Typical Value = 1.
e1
Field voltage value 1 (E1). Typical Value = 4.18.
se1
Saturation factor at E1 (S(E1)). Typical Value = 0.1.
e2
Field voltage value 2 (E2). Typical Value = 3.14.
se2
Saturation factor at E2 (S(E2)). Typical Value = 0.03.
kf
Rate feedback gain (KF). Typical Value = 0.02.
tf1
Rate feedback time constant (TF1). Typical Value = 1.
tf2
Rate feedback time constant (TF2). Typical Value = 1.
ExcAVR3
Italian excitation system. It represents exciter dynamo and electric regulator.
ka
AVR gain (KA). Typical Value = 3000.
vrmn
Maximum AVR output (VRMN). Typical Value = -7.5.
vrmx
Minimum AVR output (VRMX). Typical Value = 7.5.
t1
AVR time constant (T1). Typical Value = 220.
t2
AVR time constant (T2). Typical Value = 1.6.
t3
AVR time constant (T3). Typical Value = 0.66.
t4
AVR time constant (T4). Typical Value = 0.07.
te
Exciter time constant (TE). Typical Value = 1.
e1
Field voltage value 1 (E1). Typical Value = 4.18.
se1
Saturation factor at E1 (S(E1)). Typical Value = 0.1.
e2
Field voltage value 2 (E2). Typical Value = 3.14.
se2
Saturation factor at E2 (S(E2)). Typical Value = 0.03.
ExcAVR4
Italian excitation system. It represents static exciter and electric voltage regulator.
ka
AVR gain (KA). Typical Value = 300.
vrmn
Maximum AVR output (VRMN). Typical Value = 0.
vrmx
Minimum AVR output (VRMX). Typical Value = 5.
t1
AVR time constant (T1). Typical Value = 4.8.
t2
AVR time constant (T2). Typical Value = 1.5.
t3
AVR time constant (T3). Typical Value = 0.
t4
AVR time constant (T4). Typical Value = 0.
ke
Exciter gain (KE). Typical Value = 1.
vfmx
Maximum exciter output (VFMX). Typical Value = 5.
vfmn
Minimum exciter output (VFMN). Typical Value = 0.
kif
Exciter internal reactance (KIF). Typical Value = 0.
tif
Exciter current feedback time constant (TIF). Typical Value = 0.
t1if
Exciter current feedback time constant (T1IF). Typical Value = 60.
imul
AVR output voltage dependency selector (Imul).
true = selector is connected
false = selector is not connected.
Typical Value = true.
ExcAVR5
Manual excitation control with field circuit resistance. This model can be used as a very simple representation of manual voltage control.
ka
Gain (Ka).
ta
Time constant (Ta).
rex
Effective Output Resistance (Rex). Rex represents the effective output resistance seen by the excitation system.
ExcAVR7
IVO excitation system.
k1
Gain (K1). Typical Value = 1.
a1
Lead coefficient (A1). Typical Value = 0.5.
a2
Lag coefficient (A2). Typical Value = 0.5.
t1
Lead time constant (T1). Typical Value = 0.05.
t2
Lag time constant (T2). Typical Value = 0.1.
vmax1
Lead-lag max. limit (Vmax1). Typical Value = 5.
vmin1
Lead-lag min. limit (Vmin1). Typical Value = -5.
k3
Gain (K3). Typical Value = 3.
a3
Lead coefficient (A3). Typical Value = 0.5.
a4
Lag coefficient (A4). Typical Value = 0.5.
t3
Lead time constant (T3). Typical Value = 0.1.
t4
Lag time constant (T4). Typical Value = 0.1.
vmax3
Lead-lag max. limit (Vmax3). Typical Value = 5.
vmin3
Lead-lag min. limit (Vmin3). Typical Value = -5.
k5
Gain (K5). Typical Value = 1.
a5
Lead coefficient (A5). Typical Value = 0.5.
a6
Lag coefficient (A6). Typical Value = 0.5.
t5
Lead time constant (T5). Typical Value = 0.1.
t6
Lag time constant (T6). Typical Value = 0.1.
vmax5
Lead-lag max. limit (Vmax5). Typical Value = 5.
vmin5
Lead-lag min. limit (Vmin5). Typical Value = -2.
ExcBBC
Transformer fed static excitation system (static with ABB regulator). This model represents a static excitation system in which a gated thyristor bridge fed by a transformer at the main generator terminals feeds the main generator directly.
t1
Controller time constant (T1). Typical Value = 6.
t2
Controller time constant (T2). Typical Value = 1.
t3
Lead/lag time constant (T3). Typical Value = 0.05.
t4
Lead/lag time constant (T4). Typical Value = 0.01.
k
Steady state gain (K). Typical Value = 300.
vrmin
Minimum control element output (Vrmin). Typical Value = -5.
vrmax
Maximum control element output (Vrmax). Typical Value = 5.
efdmin
Minimum open circuit exciter voltage (Efdmin). Typical Value = -5.
efdmax
Maximum open circuit exciter voltage (Efdmax). Typical Value = 5.
xe
Effective excitation transformer reactance (Xe). Typical Value = 0.05.
switch
Supplementary signal routing selector (switch).
true = Vs connected to 3rd summing point
false = Vs connected to 1st summing point (see diagram).
Typical Value = true.
ExcCZ
Czech Proportion/Integral Exciter.
kp
Regulator proportional gain (Kp).
tc
Regulator integral time constant (Tc).
vrmax
Voltage regulator maximum limit (Vrmax).
vrmin
Voltage regulator minimum limit (Vrmin).
ka
Regulator gain (Ka).
ta
Regulator time constant (Ta).
ke
Exciter constant related to self-excited field (Ke).
te
Exciter time constant, integration rate associated with exciter control (Te).
efdmax
Exciter output maximum limit (Efdmax).
efdmin
Exciter output minimum limit (Efdmin).
ExcDC1A
Modified IEEE DC1A direct current commutator exciter with speed input and without underexcitation limiters (UEL) inputs.
ka
Voltage regulator gain (Ka). Typical Value = 46.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
ta
Voltage regulator time constant (Ta). Typical Value = 0.06.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 1.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -0.9.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.46.
kf
Excitation control system stabilizer gain (Kf). Typical Value = 0.1.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (Efd1). Typical Value = 3.1.
seefd1
Exciter saturation function value at the corresponding exciter voltage, Efd1 (Se[Eefd1]). Typical Value = 0.33.
efd2
Exciter voltage at which exciter saturation is defined (Efd2). Typical Value = 2.3.
seefd2
Exciter saturation function value at the corresponding exciter voltage, Efd1 (Se[Eefd1]). Typical Value = 0.33.
exclim
(exclim).
IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero is not applied to integrator output.
Typical Value = true.
efdmin
Minimum voltage exciter output limiter (Efdmin). Typical Value = -99.
edfmax
Maximum voltage exciter output limiter (Efdmax). Typical Value = 99.
ExcDC2A
Modified IEEE DC2A direct current commutator exciters with speed input, one more leg block in feedback loop and without underexcitation limiters (UEL) inputs. DC type 2 excitation system model with added speed multiplier, added lead-lag, and voltage-dependent limits.
ka
Voltage regulator gain (Ka). Typical Value = 300.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
ta
Voltage regulator time constant (Ta). Typical Value = 0.01.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 4.95.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -4.9.
ke
Exciter constant related to self-excited field (Ke). If Ke is entered as zero, the model calculates an effective value of Ke such that the initial condition value of Vr is zero. The zero value of Ke is not changed. If Ke is entered as non-zero, its value is used directly, without change. Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.33.
kf
Excitation control system stabilizer gain (Kf). Typical Value = 0.1.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 0.675.
tf1
Excitation control system stabilizer time constant (Tf1). Typical Value = 0.
efd1
Exciter voltage at which exciter saturation is defined (Efd1). Typical Value = 3.05.
seefd1
Exciter saturation function value at the corresponding exciter voltage, Efd1 (Se[Eefd1]). Typical Value = 0.279.
efd2
Exciter voltage at which exciter saturation is defined (Efd2). Typical Value = 2.29.
seefd2
Exciter saturation function value at the corresponding exciter voltage, Efd2 (Se[Efd2]). Typical Value = 0.117.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero is not applied to integrator output.
Typical Value = true.
vtlim
(Vtlim).
true = limiter at the block [Ka/(1+sTa)] is dependent on Vt
false = limiter at the block is not dependent on Vt.
Typical Value = true.
ExcDC3A
This is modified IEEE DC3A direct current commutator exciters with speed input, and death band. DC old type 4.
trh
Rheostat travel time (Trh). Typical Value = 20.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
kr
Death band (Kr). If Kr is not zero, the voltage regulator input changes at a constant rate if Verr > Kr or Verr < -Kr as per the IEEE (1968) Type 4 model. If Kr is zero, the error signal drives the voltage regulator continuously as per the IEEE (1980) DC3 and IEEE (1992, 2005) DC3A models. Typical Value = 0.
kv
Fast raise/lower contact setting (Kv). Typical Value = 0.05.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 5.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.83.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (Efd1). Typical Value = 2.6.
seefd1
Exciter saturation function value at the corresponding exciter voltage, Efd1 (Se[Eefd1]). Typical Value = 0.1.
efd2
Exciter voltage at which exciter saturation is defined (Efd2). Typical Value = 3.45.
seefd2
Exciter saturation function value at the corresponding exciter voltage, Efd2 (Se[Efd2]). Typical Value = 0.35.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero not applied to integrator output.
Typical Value = true.
edfmax
Maximum voltage exciter output limiter (Efdmax). Typical Value = 99.
efdmin
Minimum voltage exciter output limiter (Efdmin). Typical Value = -99.
efdlim
(Efdlim).
true = exciter output limiter is active
false = exciter output limiter not active.
Typical Value = true.
ExcDC3A1
This is modified old IEEE type 3 excitation system.
ka
Voltage regulator gain (Ka). Typical Value = 300.
ta
Voltage regulator time constant (Ta). Typical Value = 0.01.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 5.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.83.
kf
Excitation control system stabilizer gain (Kf). Typical Value = 0.1.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 0.675.
kp
Potential circuit gain coefficient (Kp). Typical Value = 4.37.
ki
Potential circuit gain coefficient (Ki). Typical Value = 4.83.
vbmax
Available exciter voltage limiter (Vbmax). Typical Value = 11.63.
exclim
(exclim).
true = lower limit of zero is applied to integrator output
false = lower limit of zero not applied to integrator output.
Typical Value = true.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
vb1max
Available exciter voltage limiter (Vb1max). Typical Value = 11.63.
vblim
Vb limiter indicator.
true = exciter Vbmax limiter is active
false = Vb1max is active.
Typical Value = true.
ExcELIN1
Static PI transformer fed excitation system: ELIN (VATECH) - simplified model. This model represents an all-static excitation system. A PI voltage controller establishes a desired field current set point for a proportional current controller. The integrator of the PI controller has a follow-up input to match its signal to the present field current. A power system stabilizer with power input is included in the model.
tfi
Current transducer time constant (Tfi). Typical Value = 0.
tnu
Controller reset time constant (Tnu). Typical Value = 2.
vpu
Voltage controller proportional gain (Vpu). Typical Value = 34.5.
vpi
Current controller gain (Vpi). Typical Value = 12.45.
vpnf
Controller follow up gain (Vpnf). Typical Value = 2.
dpnf
Controller follow up dead band (Dpnf). Typical Value = 0.
tsw
Stabilizer parameters (Tsw). Typical Value = 3.
efmin
Minimum open circuit excitation voltage (Efmin). Typical Value = -5.
efmax
Maximum open circuit excitation voltage (Efmax). Typical Value = 5.
xe
Excitation transformer effective reactance (Xe) (>=0). Xe represents the regulation of the transformer/rectifier unit. Typical Value = 0.06.
ks1
Stabilizer Gain 1 (Ks1). Typical Value = 0.
ks2
Stabilizer Gain 2 (Ks2). Typical Value = 0.
ts1
Stabilizer Phase Lag Time Constant (Ts1). Typical Value = 1.
ts2
Stabilizer Filter Time Constant (Ts2). Typical Value = 1.
smax
Stabilizer Limit Output (smax). Typical Value = 0.1.
ExcELIN2
Detailed Excitation System Model - ELIN (VATECH). This model represents an all-static excitation system. A PI voltage controller establishes a desired field current set point for a proportional current controller. The integrator of the PI controller has a follow-up input to match its signal to the present field current. Power system stabilizer models used in conjunction with this excitation system model: PssELIN2, PssIEEE2B, Pss2B.
k1
Voltage regulator input gain (K1). Typical Value = 0.
k1ec
Voltage regulator input limit (K1ec). Typical Value = 2.
kd1
Voltage controller derivative gain (Kd1). Typical Value = 34.5.
tb1
Voltage controller derivative washout time constant (Tb1). Typical Value = 12.45.
pid1max
Controller follow up gain (PID1max). Typical Value = 2.
ti1
Controller follow up dead band (Ti1). Typical Value = 0.
iefmax2
Minimum open circuit excitation voltage (Iefmax2). Typical Value = -5.
k2
Gain (K2). Typical Value = 5.
ketb
Gain (Ketb). Typical Value = 0.06.
upmax
Limiter (Upmax). Typical Value = 3.
upmin
Limiter (Upmin). Typical Value = 0.
te
Time constant (Te). Typical Value = 0.
xp
Excitation transformer effective reactance (Xp). Typical Value = 1.
te2
Time Constant (Te2). Typical Value = 1.
ke2
Gain (Ke2). Typical Value = 0.1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1). Typical Value = 3.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 0.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 1.
tr4
Time constant (Tr4). Typical Value = 1.
k3
Gain (K3). Typical Value = 0.1.
ti3
Time constant (Ti3). Typical Value = 3.
k4
Gain (K4). Typical Value = 0.
ti4
Time constant (Ti4). Typical Value = 0.
iefmax
Limiter (Iefmax). Typical Value = 1.
iefmin
Limiter (Iefmin). Typical Value = 1.
efdbas
Gain (Efdbas). Typical Value = 0.1.
ExcHU
Hungarian Excitation System Model, with built-in voltage transducer.
tr
Filter time constant (Tr). If a voltage compensator is used in conjunction with this excitation system model, Tr should be set to 0. Typical Value = 0.01.
te
Major loop PI tag integration time constant (Te). Typical Value = 0.154.
imin
Major loop PI tag output signal lower limit (Imin). Typical Value = 0.1.
imax
Major loop PI tag output signal upper limit (Imax). Typical Value = 2.19.
ae
Major loop PI tag gain factor (Ae). Typical Value = 3.
emin
Field voltage control signal lower limit on AVR base (Emin). Typical Value = -0.866.
emax
Field voltage control signal upper limit on AVR base (Emax). Typical Value = 0.996.
ki
Current base conversion constant (Ki). Typical Value = 0.21428.
ai
Minor loop PI tag gain factor (Ai). Typical Value = 22.
ti
Minor loop PI control tag integration time constant (Ti). Typical Value = 0.01333.
atr
AVR constant (Atr). Typical Value = 2.19.
ke
Voltage base conversion constant (Ke). Typical Value = 4.666.
ExcOEX3T
Modified IEEE Type ST1 Excitation System with semi-continuous and acting terminal voltage limiter.
t1
Time constant (T1).
t2
Time constant (T2).
t3
Time constant (T3).
t4
Time constant (T4).
ka
Gain (KA).
t5
Time constant (T5).
t6
Time constant (T6).
vrmax
Limiter (VRMAX).
vrmin
Limiter (VRMIN).
te
Time constant (TE).
kf
Gain (KF).
tf
Time constant (TF).
kc
Gain (KC).
kd
Gain (KD).
ke
Gain (KE).
e1
Saturation parameter (E1).
see1
Saturation parameter (SE(E1)).
e2
Saturation parameter (E2).
see2
Saturation parameter (SE(E2)).
ExcPIC
Proportional/Integral Regulator Excitation System Model. This model can be used to represent excitation systems with a proportional-integral (PI) voltage regulator controller.
ka
PI controller gain (Ka). Typical Value = 3.15.
ta1
PI controller time constant (Ta1). Typical Value = 1.
vr1
PI maximum limit (Vr1). Typical Value = 1.
vr2
PI minimum limit (Vr2). Typical Value = -0.87.
ta2
Voltage regulator time constant (Ta2). Typical Value = 0.01.
ta3
Lead time constant (Ta3). Typical Value = 0.
ta4
Lag time constant (Ta4). Typical Value = 0.
vrmax
Voltage regulator maximum limit (Vrmax). Typical Value = 1.
vrmin
Voltage regulator minimum limit (Vrmin). Typical Value = -0.87.
kf
Rate feedback gain (Kf). Typical Value = 0.
tf1
Rate feedback time constant (Tf1). Typical Value = 0.
tf2
Rate feedback lag time constant (Tf2). Typical Value = 0.
efdmax
Exciter maximum limit (Efdmax). Typical Value = 8.
efdmin
Exciter minimum limit (Efdmin). Typical Value = -0.87.
ke
Exciter constant (Ke). Typical Value = 0.
te
Exciter time constant (Te). Typical Value = 0.
e1
Field voltage value 1 (E1). Typical Value = 0.
se1
Saturation factor at E1 (Se1). Typical Value = 0.
e2
Field voltage value 2 (E2). Typical Value = 0.
se2
Saturation factor at E2 (Se2). Typical Value = 0.
kp
Potential source gain (Kp). Typical Value = 6.5.
ki
Current source gain (Ki). Typical Value = 0.
kc
Exciter regulation factor (Kc). Typical Value = 0.08.
ExcREXS
General Purpose Rotating Excitation System Model. This model can be used to represent a wide range of excitation systems whose DC power source is an AC or DC generator. It encompasses IEEE type AC1, AC2, DC1, and DC2 excitation system models.
e1
Field voltage value 1 (E1). Typical Value = 3.
e2
Field voltage value 2 (E2). Typical Value = 4.
fbf
Rate feedback signal flag (Fbf). Typical Value = fieldCurrent.
flimf
Limit type flag (Flimf). Typical Value = 0.
kc
Rectifier regulation factor (Kc). Typical Value = 0.05.
kd
Exciter regulation factor (Kd). Typical Value = 2.
ke
Exciter field proportional constant (Ke). Typical Value = 1.
kefd
Field voltage feedback gain (Kefd). Typical Value = 0.
kf
Rate feedback gain (Kf). Typical Value = 0.05.
kh
Field voltage controller feedback gain (Kh). Typical Value = 0.
kii
Field Current Regulator Integral Gain (Kii). Typical Value = 0.
kip
Field Current Regulator Proportional Gain (Kip). Typical Value = 1.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
kvi
Voltage Regulator Integral Gain (Kvi). Typical Value = 0.
kvp
Voltage Regulator Proportional Gain (Kvp). Typical Value = 2800.
kvphz
V/Hz limiter gain (Kvphz). Typical Value = 0.
nvphz
Pickup speed of V/Hz limiter (Nvphz). Typical Value = 0.
se1
Saturation factor at E1 (Se1). Typical Value = 0.0001.
se2
Saturation factor at E2 (Se2). Typical Value = 0.001.
ta
Voltage Regulator time constant (Ta). Typical Value = 0.01.
tb1
Lag time constant (Tb1). Typical Value = 0.
tb2
Lag time constant (Tb2). Typical Value = 0.
tc1
Lead time constant (Tc1). Typical Value = 0.
tc2
Lead time constant (Tc2). Typical Value = 0.
te
Exciter field time constant (Te). Typical Value = 1.2.
tf
Rate feedback time constant (Tf). Typical Value = 1.
tf1
Feedback lead time constant (Tf1). Typical Value = 0.
tf2
Feedback lag time constant (Tf2). Typical Value = 0.
tp
Field current Bridge time constant (Tp). Typical Value = 0.
vcmax
Maximum compounding voltage (Vcmax). Typical Value = 0.
vfmax
Maximum Exciter Field Current (Vfmax). Typical Value = 47.
vfmin
Minimum Exciter Field Current (Vfmin). Typical Value = -20.
vimax
Voltage Regulator Input Limit (Vimax). Typical Value = 0.1.
vrmax
Maximum controller output (Vrmax). Typical Value = 47.
vrmin
Minimum controller output (Vrmin). Typical Value = -20.
xc
Exciter compounding reactance (Xc). Typical Value = 0.
ExcSCRX
Simple excitation system model representing generic characteristics of many excitation systems; intended for use where negative field current may be a problem.
tatb
Ta/Tb - gain reduction ratio of lag-lead element (TaTb). The parameter Ta is not defined explicitly. Typical Value = 0.1.
tb
Denominator time constant of lag-lead block (Tb). Typical Value = 10.
k
Gain (K) (>0). Typical Value = 200.
te
Time constant of gain block (Te) (>0). Typical Value = 0.02.
emin
Minimum field voltage output (Emin). Typical Value = 0.
emax
Maximum field voltage output (Emax). Typical Value = 5.
cswitch
Power source switch (Cswitch).
true = fixed voltage of 1.0 PU
false = generator terminal voltage.
rcrfd
Rc/Rfd - ratio of field discharge resistance to field winding resistance (RcRfd). Typical Value = 0.
ExcSEXS
Simplified Excitation System Model.
tatb
Ta/Tb - gain reduction ratio of lag-lead element (TaTb). Typical Value = 0.1.
tb
Denominator time constant of lag-lead block (Tb). Typical Value = 10.
k
Gain (K) (>0). Typical Value = 100.
te
Time constant of gain block (Te). Typical Value = 0.05.
emin
Minimum field voltage output (Emin). Typical Value = -5.
emax
Maximum field voltage output (Emax). Typical Value = 5.
kc
PI controller gain (Kc). Typical Value = 0.08.
tc
PI controller phase lead time constant (Tc). Typical Value = 0.
efdmin
Field voltage clipping minimum limit (Efdmin). Typical Value = -5.
efdmax
Field voltage clipping maximum limit (Efdmax). Typical Value = 5.
ExcSK
Slovakian Excitation System Model. UEL and secondary voltage control are included in this model. When this model is used, there cannot be a separate underexcitation limiter or VAr controller model.
efdmax
Field voltage clipping limit (Efdmax).
efdmin
Field voltage clipping limit (Efdmin).
emax
Maximum field voltage output (Emax). Typical Value = 20.
emin
Minimum field voltage output (Emin). Typical Value = -20.
k
Gain (K). Typical Value = 1.
k1
Parameter of underexcitation limit (K1). Typical Value = 0.1364.
k2
Parameter of underexcitation limit (K2). Typical Value = -0.3861.
kc
PI controller gain (Kc). Typical Value = 70.
kce
Rectifier regulation factor (Kce). Typical Value = 0.
kd
Exciter internal reactance (Kd). Typical Value = 0.
kgob
P controller gain (Kgob). Typical Value = 10.
kp
PI controller gain (Kp). Typical Value = 1.
kqi
PI controller gain of integral component (Kqi). Typical Value = 0.
kqob
Rate of rise of the reactive power (Kqob).
kqp
PI controller gain (Kqp). Typical Value = 0.
nq
Dead band of reactive power (nq). Determines the range of sensitivity. Typical Value = 0.001.
qconoff
Secondary voltage control state (Qc_on_off).
true = secondary voltage control is ON
false = secondary voltage control is OFF.
Typical Value = false.
qz
Desired value (setpoint) of reactive power, manual setting (Qz).
remote
Selector to apply automatic calculation in secondary controller model.
true = automatic calculation is activated
false = manual set is active; the use of desired value of reactive power (Qz) is required.
Typical Value = true.
sbase
Apparent power of the unit (Sbase). Unit = MVA. Typical Value = 259.
ApparentPower
Product of the RMS value of the voltage and the RMS value of the current.
CIMDatatype
value
unit
multiplier
tc
PI controller phase lead time constant (Tc). Typical Value = 8.
te
Time constant of gain block (Te). Typical Value = 0.1.
ti
PI controller phase lead time constant (Ti). Typical Value = 2.
tp
Time constant (Tp). Typical Value = 0.1.
tr
Voltage transducer time constant (Tr). Typical Value = 0.01.
uimax
Maximum error (Uimax). Typical Value = 10.
uimin
Minimum error (UImin). Typical Value = -10.
urmax
Maximum controller output (URmax). Typical Value = 10.
urmin
Minimum controller output (URmin). Typical Value = -10.
vtmax
Maximum terminal voltage input (Vtmax). Determines the range of voltage dead band. Typical Value = 1.05.
vtmin
Minimum terminal voltage input (Vtmin). Determines the range of voltage dead band. Typical Value = 0.95.
yp
Maximum output (Yp). Minimum output = 0. Typical Value = 1.
ExcST1A
Modification of an old IEEE ST1A static excitation system without overexcitation limiter (OEL) and underexcitation limiter (UEL).
vimax
Maximum voltage regulator input limit (Vimax). Typical Value = 999.
vimin
Minimum voltage regulator input limit (Vimin). Typical Value = -999.
tc
Voltage regulator time constant (Tc). Typical Value = 1.
tb
Voltage regulator time constant (Tb). Typical Value = 10.
ka
Voltage regulator gain (Ka). Typical Value = 190.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vrmax
Maximum voltage regulator outputs (Vrmax). Typical Value = 7.8.
vrmin
Minimum voltage regulator outputs (Vrmin). Typical Value = -6.7.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.05.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
tc1
Voltage regulator time constant (Tc1). Typical Value = 0.
tb1
Voltage regulator time constant (Tb1). Typical Value = 0.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 999.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -999.
ilr
Exciter output current limit reference (Ilr). Typical Value = 0.
klr
Exciter output current limiter gain (Klr). Typical Value = 0.
xe
Excitation xfmr effective reactance (Xe). Typical Value = 0.04.
ExcST2A
Modified IEEE ST2A static excitation system - another lead-lag block added to match the model defined by WECC.
ka
Voltage regulator gain (Ka). Typical Value = 120.
ta
Voltage regulator time constant (Ta). Typical Value = 0.15.
vrmax
Maximum voltage regulator outputs (Vrmax). Typical Value = 1.
vrmin
Minimum voltage regulator outputs (Vrmin). Typical Value = -1.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.5.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.05.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 0.7.
kp
Potential circuit gain coefficient (Kp). Typical Value = 4.88.
ki
Potential circuit gain coefficient (Ki). Typical Value = 8.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 1.82.
efdmax
Maximum field voltage (Efdmax). Typical Value = 99.
uelin
UEL input (UELin).
true = HV gate
false = add to error signal.
Typical Value = false.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ExcST3A
Modified IEEE ST3A static excitation system with added speed multiplier.
vimax
Maximum voltage regulator input limit (Vimax). Typical Value = 0.2.
vimin
Minimum voltage regulator input limit (Vimin). Typical Value = -0.2.
kj
AVR gain (Kj). Typical Value = 200.
tb
Voltage regulator time constant (Tb). Typical Value = 6.67.
tc
Voltage regulator time constant (Tc). Typical Value = 1.
efdmax
Maximum AVR output (Efdmax). Typical Value = 6.9.
km
Forward gain constant of the inner loop field regulator (Km). Typical Value = 7.04.
tm
Forward time constant of inner loop field regulator (Tm). Typical Value = 1.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 1.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = 0.
kg
Feedback gain constant of the inner loop field regulator (Kg). Typical Value = 1.
kp
Potential source gain (Kp) (>0). Typical Value = 4.37.
thetap
Potential circuit phase angle (thetap). Typical Value = 20.
ki
Potential circuit gain coefficient (Ki). Typical Value = 4.83.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 1.1.
xl
Reactance associated with potential source (Xl). Typical Value = 0.09.
vbmax
Maximum excitation voltage (Vbmax). Typical Value = 8.63.
vgmax
Maximum inner loop feedback voltage (Vgmax). Typical Value = 6.53.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
ks1
Coefficient to allow different usage of the model-speed coefficient (Ks1). Typical Value = 0.
ExcST4B
Modified IEEE ST4B static excitation system with maximum inner loop feedback gain Vgmax.
kpr
Voltage regulator proportional gain (Kpr). Typical Value = 10.75.
kir
Voltage regulator integral gain (Kir). Typical Value = 10.75.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 1.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -0.87.
kpm
Voltage regulator proportional gain output (Kpm). Typical Value = 1.
kim
Voltage regulator integral gain output (Kim). Typical Value = 0.
vmmax
Maximum inner loop output (Vmmax). Typical Value = 99.
vmmin
Minimum inner loop output (Vmmin). Typical Value = -99.
kg
Feedback gain constant of the inner loop field regulator (Kg). Typical Value = 0.
kp
Potential circuit gain coefficient (Kp). Typical Value = 9.3.
thetap
Potential circuit phase angle (thetap). Typical Value = 0.
ki
Potential circuit gain coefficient (Ki). Typical Value = 0.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.113.
xl
Reactance associated with potential source (Xl). Typical Value = 0.124.
vbmax
Maximum excitation voltage (Vbmax). Typical Value = 11.63.
vgmax
Maximum inner loop feedback voltage (Vgmax). Typical Value = 5.8.
uel
Selector (Uel).
true = UEL is part of block diagram
false = UEL is not part of block diagram.
Typical Value = false.
lvgate
Selector (LVgate).
true = LVgate is part of the block diagram
false = LVgate is not part of the block diagram.
Typical Value = false.
ExcST6B
Modified IEEE ST6B static excitation system with PID controller and optional inner feedbacks loop.
ilr
Exciter output current limit reference (Ilr). Typical Value = 4.164.
k1
Selector (K1).
true = feedback is from Ifd
false = feedback is not from Ifd.
Typical Value = true.
kcl
Exciter output current limit adjustment (Kcl). Typical Value = 1.0577.
kff
Pre-control gain constant of the inner loop field regulator (Kff). Typical Value = 1.
kg
Feedback gain constant of the inner loop field regulator (Kg). Typical Value = 1.
kia
Voltage regulator integral gain (Kia). Typical Value = 45.094.
klr
Exciter output current limit adjustment (Kcl). Typical Value = 17.33.
km
Forward gain constant of the inner loop field regulator (Km). Typical Value = 1.
kpa
Voltage regulator proportional gain (Kpa). Typical Value = 18.038.
kvd
Voltage regulator derivative gain (Kvd). Typical Value = 0.
oelin
OEL input selector (OELin). Typical Value = noOELinput.
tg
Feedback time constant of inner loop field voltage regulator (Tg). Typical Value = 0.02.
ts
Rectifier firing time constant (Ts). Typical Value = 0.
tvd
Voltage regulator derivative gain (Tvd). Typical Value = 0.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 4.81.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -3.85.
vilim
Selector (Vilim).
true = Vimin-Vimax limiter is active
false = Vimin-Vimax limiter is not active.
Typical Value = true.
vimax
Maximum voltage regulator input limit (Vimax). Typical Value = 10.
vimin
Minimum voltage regulator input limit (Vimin). Typical Value = -10.
vmult
Selector (Vmult).
true = multiply regulator output by terminal voltage
false = do not multiply regulator output by terminal voltage.
Typical Value = true.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 4.81.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -3.85.
xc
Excitation source reactance (Xc). Typical Value = 0.05.
ExcST7B
Modified IEEE ST7B static excitation system without stator current limiter (SCL) and current compensator (DROOP) inputs.
kh
High-value gate feedback gain (Kh). Typical Value = 1.
kia
Voltage regulator integral gain (Kia). Typical Value = 1.
kl
Low-value gate feedback gain (Kl). Typical Value = 1.
kpa
Voltage regulator proportional gain (Kpa). Typical Value = 40.
oelin
OEL input selector (OELin). Typical Value = noOELinput.
tb
Regulator lag time constant (Tb). Typical Value = 1.
tc
Regulator lead time constant (Tc). Typical Value = 1.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
tg
Feedback time constant of inner loop field voltage regulator (Tg). Typical Value = 1.
tia
Feedback time constant (Tia). Typical Value = 3.
ts
Rectifier firing time constant (Ts). Typical Value = 0.
uelin
UEL input selector (UELin). Typical Value = noUELinput.
vmax
Maximum voltage reference signal (Vmax). Typical Value = 1.1.
vmin
Minimum voltage reference signal (Vmin). Typical Value = 0.9.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 5.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -4.5.
OverexcitationLimiterDynamics
Overexcitation limiters (OELs) are also referred to as maximum excitation limiters and field current limiters. The possibility of voltage collapse in stressed power systems increases the importance of modelling these limiters in studies of system conditions that cause machines to operate at high levels of excitation for a sustained period, such as voltage collapse or system-islanding. Such events typically occur over a long time frame compared with transient or small-signal stability simulations.
OverexcitationLimiterDynamics
OOverexcitation limiter function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
OverexcLimIEEE
The over excitation limiter model is intended to represent the significant features of OELs necessary for some large-scale system studies. It is the result of a pragmatic approach to obtain a model that can be widely applied with attainable data from generator owners. An attempt to include all variations in the functionality of OELs and duplicate how they interact with the rest of the excitation systems would likely result in a level of application insufficient for the studies for which they are intended.
Reference: IEEE OEL 421.5-2005 Section 9.
itfpu
OEL timed field current limiter pickup level (ITFPU). Typical Value = 1.05.
ifdmax
OEL instantaneous field current limit (IFDMAX). Typical Value = 1.5.
ifdlim
OEL timed field current limit (IFDLIM). Typical Value = 1.05.
hyst
OEL pickup/drop-out hysteresis (HYST). Typical Value = 0.03.
kcd
OEL cooldown gain (KCD). Typical Value = 1.
kramp
OEL ramped limit rate (KRAMP). Unit = PU/sec. Typical Value = 10.
OverexcLim2
Different from LimIEEEOEL, LimOEL2 has a fixed pickup threshold and reduces the excitation set-point by mean of non-windup integral regulator.
Irated is the rated machine excitation current (calculated from nameplate conditions: Vnom, Pnom, CosPhinom).
koi
Gain Over excitation limiter (KOI). Typical Value = 0.1.
voimax
Maximum error signal (VOIMAX). Typical Value = 0.
voimin
Minimum error signal (VOIMIN). Typical Value = -9999.
ifdlim
Limit value of rated field current (IFDLIM). Typical Value = 1.05.
OverexcLimX1
Field voltage over excitation limiter.
efdrated
Rated field voltage (EFDRATED). Typical Value = 1.05.
efd1
Low voltage point on the inverse time characteristic (EFD1). Typical Value = 1.1.
t1
Time to trip the exciter at the low voltage point on the inverse time characteristic (TIME1). Typical Value = 120.
efd2
Mid voltage point on the inverse time characteristic (EFD2). Typical Value = 1.2.
t2
Time to trip the exciter at the mid voltage point on the inverse time characteristic (TIME2). Typical Value = 40.
efd3
High voltage point on the inverse time characteristic (EFD3). Typical Value = 1.5.
t3
Time to trip the exciter at the high voltage point on the inverse time characteristic (TIME3). Typical Value = 15.
efddes
Desired field voltage (EFDDES). Typical Value = 0.9.
kmx
Gain (KMX). Typical Value = 0.01.
vlow
Low voltage limit (VLOW) (>0).
OverexcLimX2
Field Voltage or Current overexcitation limiter designed to protect the generator field of an AC machine with automatic excitation control from overheating due to prolonged overexcitation.
m
(m).
true = IFD limiting
false = EFD limiting.
efdrated
Rated field voltage if m=F or field current if m=T (EFDRATED). Typical Value = 1.05.
efd1
Low voltage or current point on the inverse time characteristic (EFD1). Typical Value = 1.1.
t1
Time to trip the exciter at the low voltage or current point on the inverse time characteristic (TIME1). Typical Value = 120.
efd2
Mid voltage or current point on the inverse time characteristic (EFD2). Typical Value = 1.2.
t2
Time to trip the exciter at the mid voltage or current point on the inverse time characteristic (TIME2). Typical Value = 40.
efd3
High voltage or current point on the inverse time characteristic (EFD3). Typical Value = 1.5.
t3
Time to trip the exciter at the high voltage or current point on the inverse time characteristic (TIME3). Typical Value = 15.
efddes
Desired field voltage if m=F or field current if m=T (EFDDES). Typical Value = 1.
kmx
Gain (KMX). Typical Value = 0.002.
vlow
Low voltage limit (VLOW) (>0).
UnderexcitationLimiterDynamics
Underexcitation limiters (UELs) act to boost excitation. The UEL typically senses either a combination of voltage and current of the synchronous machine or a combination of real and reactive power. Some UELs utilize a temperature or pressure recalibration feature, in which the UEL characteristic is shifted depending upon the generator cooling gas temperature or pressure.
UnderexcitationLimiterDynamics
Underexcitation limiter function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
UnderexcLimIEEE1
The class represents the Type UEL1 model which has a circular limit boundary when plotted in terms of machine reactive power vs. real power output.
Reference: IEEE UEL1 421.5-2005 Section 10.1.
kur
UEL radius setting (KUR). Typical Value = 1.95.
kuc
UEL center setting (KUC). Typical Value = 1.38.
kuf
UEL excitation system stabilizer gain (KUF). Typical Value = 3.3.
vurmax
UEL maximum limit for radius phasor magnitude (VURMAX). Typical Value = 5.8.
vucmax
UEL maximum limit for operating point phasor magnitude (VUCMAX). Typical Value = 5.8.
kui
UEL integral gain (KUI). Typical Value = 0.
kul
UEL proportional gain (KUL). Typical Value = 100.
vuimax
UEL integrator output maximum limit (VUIMAX).
vuimin
UEL integrator output minimum limit (VUIMIN).
tu1
UEL lead time constant (TU1). Typical Value = 0.
tu2
UEL lag time constant (TU2). Typical Value = 0.05.
tu3
UEL lead time constant (TU3). Typical Value = 0.
tu4
UEL lag time constant (TU4). Typical Value = 0.
vulmax
UEL output maximum limit (VULMAX). Typical Value = 18.
vulmin
UEL output minimum limit (VULMIN). Typical Value = -18.
UnderexcLimIEEE2
The class represents the Type UEL2 which has either a straight-line or multi-segment characteristic when plotted in terms of machine reactive power output vs. real power output.
Reference: IEEE UEL2 421.5-2005 Section 10.2. (Limit characteristic lookup table shown in Figure 10.4 (p 32) of the standard).
tuv
Voltage filter time constant (TUV). Typical Value = 5.
tup
Real power filter time constant (TUP). Typical Value = 5.
tuq
Reactive power filter time constant (TUQ). Typical Value = 0.
kui
UEL integral gain (KUI). Typical Value = 0.5.
kul
UEL proportional gain (KUL). Typical Value = 0.8.
vuimax
UEL integrator output maximum limit (VUIMAX). Typical Value = 0.25.
vuimin
UEL integrator output minimum limit (VUIMIN). Typical Value = 0.
kuf
UEL excitation system stabilizer gain (KUF). Typical Value = 0.
kfb
Gain associated with optional integrator feedback input signal to UEL (KFB). Typical Value = 0.
tul
Time constant associated with optional integrator feedback input signal to UEL (TUL). Typical Value = 0.
tu1
UEL lead time constant (TU1). Typical Value = 0.
tu2
UEL lag time constant (TU2). Typical Value = 0.
tu3
UEL lead time constant (TU3). Typical Value = 0.
tu4
UEL lag time constant (TU4). Typical Value = 0.
vulmax
UEL output maximum limit (VULMAX). Typical Value = 0.25.
vulmin
UEL output minimum limit (VULMIN). Typical Value = 0.
p0
Real power values for endpoints (P0). Typical Value = 0.
q0
Reactive power values for endpoints (Q0). Typical Value = -0.31.
p1
Real power values for endpoints (P1). Typical Value = 0.3.
q1
Reactive power values for endpoints (Q1). Typical Value = -0.31.
p2
Real power values for endpoints (P2). Typical Value = 0.6.
q2
Reactive power values for endpoints (Q2). Typical Value = -0.28.
p3
Real power values for endpoints (P3). Typical Value = 0.9.
q3
Reactive power values for endpoints (Q3). Typical Value = -0.21.
p4
Real power values for endpoints (P4). Typical Value = 1.02.
q4
Reactive power values for endpoints (Q4). Typical Value = 0.
p5
Real power values for endpoints (P5).
q5
Reactive power values for endpoints (Q5).
p6
Real power values for endpoints (P6).
q6
Reactive power values for endpoints (Q6).
p7
Real power values for endpoints (P7).
q7
Reactive power values for endpoints (Q7).
p8
Real power values for endpoints (P8).
q8
Reactive power values for endpoints (Q8).
p9
Real power values for endpoints (P9).
q9
Reactive power values for endpoints (Q9).
p10
Real power values for endpoints (P10).
q10
Reactive power values for endpoints (Q10).
k1
UEL terminal voltage exponent applied to real power input to UEL limit look-up table (k1). Typical Value = 2.
k2
UEL terminal voltage exponent applied to reactive power output from UEL limit look-up table (k2). Typical Value = 2.
UnderexcLim2Simplified
This model can be derived from UnderexcLimIEEE2.
The limit characteristic (look –up table) is a single straight-line, the same as UnderexcLimIEEE2 (see Figure 10.4 (p 32), IEEE 421.5-2005 Section 10.2).
q0
Segment Q initial point (Q0). Typical Value = -0.31.
q1
Segment Q end point (Q1). Typical Value = -0.1.
p0
Segment P initial point (P0). Typical Value = 0.
p1
Segment P end point (P1). Typical Value = 1.
kui
Gain Under excitation limiter (Kui). Typical Value = 0.1.
vuimin
Minimum error signal (VUImin). Typical Value = 0.
vuimax
Maximum error signal (VUImax). Typical Value = 1.
UnderexcLimX1
Allis-Chalmers minimum excitation limiter.
kf2
Differential gain (Kf2).
tf2
Differential time constant (Tf2) (>0).
km
Minimum excitation limit gain (Km).
tm
Minimum excitation limit time constant (Tm).
melmax
Minimum excitation limit value (MELMAX).
k
Minimum excitation limit slope (K) (>0).
UnderexcLimX2
Westinghouse minimum excitation limiter.
kf2
Differential gain (Kf2).
tf2
Differential time constant (Tf2) (>0).
km
Minimum excitation limit gain (Km).
tm
Minimum excitation limit time constant (Tm).
melmax
Minimum excitation limit value (MELMAX).
qo
Excitation center setting (Qo).
r
Excitation radius (R).
PowerSystemStabilizerDynamics
The power system stabilizer (PSS) model provides an input (Vs) to the excitation system model to improve damping of system oscillations. A variety of input signals may be used depending on the particular design.
PowerSystemStabilizerDynamics
Power system stabilizer function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
PssIEEE1A
The class represents IEEE Std 421.5-2005 type PSS1A power system stabilizer model. PSS1A is the generalized form of a PSS with a single input. Some common stabilizer input signals are speed, frequency, and power.
Reference: IEEE 1A 421.5-2005 Section 8.1.
inputSignalType
Type of input signal. Typical Value = rotorAngularFrequencyDeviation.
InputSignalKind
Input signal type. In Dynamics modelling, commonly represented by j parameter.
rotorSpeed
Input signal is rotor or shaft speed (angular frequency).
rotorAngularFrequencyDeviation
Input signal is rotor or shaft angular frequency deviation.
busFrequency
Input signal is bus voltage frequency. This could be a terminal frequency or remote frequency.
busFrequencyDeviation
Input signal is deviation of bus voltage frequency. This could be a terminal frequency deviation or remote frequency deviation.
generatorElectricalPower
Input signal is generator electrical power on rated S.
generatorAcceleratingPower
Input signal is generating accelerating power.
busVoltage
Input signal is bus voltage. This could be a terminal voltage or remote voltage.
busVoltageDerivative
Input signal is derivative of bus voltage. This could be a terminal voltage derivative or remote voltage derivative.
branchCurrent
Input signal is amplitude of remote branch current.
fieldCurrent
Input signal is generator field current.
a1
PSS signal conditioning frequency filter constant (A1). Typical Value = 0.061.
a2
PSS signal conditioning frequency filter constant (A2). Typical Value = 0.0017.
t1
Lead/lag time constant (T1). Typical Value = 0.3.
t2
Lead/lag time constant (T2). Typical Value = 0.03.
t3
Lead/lag time constant (T3). Typical Value = 0.3.
t4
Lead/lag time constant (T4). Typical Value = 0.03.
t5
Washout time constant (T5). Typical Value = 10.
t6
Transducer time constant (T6). Typical Value = 0.01.
ks
Stabilizer gain (Ks). Typical Value = 5.
vrmax
Maximum stabilizer output (Vrmax). Typical Value = 0.05.
vrmin
Minimum stabilizer output (Vrmin). Typical Value = -0.05.
PssIEEE2B
The class represents IEEE Std 421.5-2005 type PSS2B power system stabilizer model. This stabilizer model is designed to represent a variety of dual-input stabilizers, which normally use combinations of power and speed or frequency to derive the stabilizing signal.
Reference: IEEE 2B 421.5-2005 Section 8.2.
inputSignal1Type
Type of input signal #1. Typical Value = rotorSpeed.
inputSignal2Type
Type of input signal #2. Typical Value = generatorElectricalPower.
vsi1max
Input signal #1 max limit (Vsi1max). Typical Value = 2.
vsi1min
Input signal #1 min limit (Vsi1min). Typical Value = -2.
tw1
First washout on signal #1 (Tw1). Typical Value = 2.
tw2
Second washout on signal #1 (Tw2). Typical Value = 2.
vsi2max
Input signal #2 max limit (Vsi2max). Typical Value = 2.
vsi2min
Input signal #2 min limit (Vsi2min). Typical Value = -2.
tw3
First washout on signal #2 (Tw3). Typical Value = 2.
tw4
Second washout on signal #2 (Tw4). Typical Value = 0.
t1
Lead/lag time constant (T1). Typical Value = 0.12.
t2
Lead/lag time constant (T2). Typical Value = 0.02.
t3
Lead/lag time constant (T3). Typical Value = 0.3.
t4
Lead/lag time constant (T4). Typical Value = 0.02.
t6
Time constant on signal #1 (T6). Typical Value = 0.
t7
Time constant on signal #2 (T7). Typical Value = 2.
t8
Lead of ramp tracking filter (T8). Typical Value = 0.2.
t9
Lag of ramp tracking filter (T9). Typical Value = 0.1.
t10
Lead/lag time constant (T10). Typical Value = 0.
t11
Lead/lag time constant (T11). Typical Value = 0.
ks1
Stabilizer gain (Ks1). Typical Value = 12.
ks2
Gain on signal #2 (Ks2). Typical Value = 0.2.
ks3
Gain on signal #2 input before ramp-tracking filter (Ks3). Typical Value = 1.
n
Order of ramp tracking filter (N). Typical Value = 1.
m
Denominator order of ramp tracking filter (M). Typical Value = 5.
vstmax
Stabilizer output max limit (Vstmax). Typical Value = 0.1.
vstmin
Stabilizer output min limit (Vstmin). Typical Value = -0.1.
PssIEEE3B
The class represents IEEE Std 421.5-2005 type PSS3B power system stabilizer model. The PSS model PSS3B has dual inputs of electrical power and rotor angular frequency deviation. The signals are used to derive an equivalent mechanical power signal.
Reference: IEEE 3B 421.5-2005 Section 8.3.
inputSignal1Type
Type of input signal #1. Typical Value = generatorElectricalPower.
inputSignal2Type
Type of input signal #2. Typical Value = rotorSpeed.
t1
Transducer time constant (T1). Typical Value = 0.012.
t2
Transducer time constant (T2). Typical Value = 0.012.
tw1
Washout time constant (Tw1). Typical Value = 0.3.
tw2
Washout time constant (Tw2). Typical Value = 0.3.
tw3
Washout time constant (Tw3). Typical Value = 0.6.
ks1
Gain on signal # 1 (Ks1). Typical Value = -0.602.
ks2
Gain on signal # 2 (Ks2). Typical Value = 30.12.
a1
Notch filter parameter (A1). Typical Value = 0.359.
a2
Notch filter parameter (A2). Typical Value = 0.586.
a3
Notch filter parameter (A3). Typical Value = 0.429.
a4
Notch filter parameter (A4). Typical Value = 0.564.
a5
Notch filter parameter (A5). Typical Value = 0.001.
a6
Notch filter parameter (A6). Typical Value = 0.
a7
Notch filter parameter (A7). Typical Value = 0.031.
a8
Notch filter parameter (A8). Typical Value = 0.
vstmax
Stabilizer output max limit (Vstmax). Typical Value = 0.1.
vstmin
Stabilizer output min limit (Vstmin). Typical Value = -0.1.
PssIEEE4B
The class represents IEEE Std 421.5-2005 type PSS2B power system stabilizer model. The PSS4B model represents a structure based on multiple working frequency bands. Three separate bands, respectively dedicated to the low-, intermediate- and high-frequency modes of oscillations, are used in this delta-omega (speed input) PSS.
Reference: IEEE 4B 421.5-2005 Section 8.4.
bwh1
Notch filter 1 (high-frequency band): Three dB bandwidth (Bwi).
bwh2
Notch filter 2 (high-frequency band): Three dB bandwidth (Bwi).
bwl1
Notch filter 1 (low-frequency band): Three dB bandwidth (Bwi).
bwl2
Notch filter 2 (low-frequency band): Three dB bandwidth (Bwi).
kh
High band gain (KH). Typical Value = 120.
kh1
High band differential filter gain (KH1). Typical Value = 66.
kh11
High band first lead-lag blocks coefficient (KH11). Typical Value = 1.
kh17
High band first lead-lag blocks coefficient (KH17). Typical Value = 1.
kh2
High band differential filter gain (KH2). Typical Value = 66.
ki
Intermediate band gain (KI). Typical Value = 30.
ki1
Intermediate band differential filter gain (KI1). Typical Value = 66.
ki11
Intermediate band first lead-lag blocks coefficient (KI11). Typical Value = 1.
ki17
Intermediate band first lead-lag blocks coefficient (KI17). Typical Value = 1.
ki2
Intermediate band differential filter gain (KI2). Typical Value = 66.
kl
Low band gain (KL). Typical Value = 7.5.
kl1
Low band differential filter gain (KL1). Typical Value = 66.
kl11
Low band first lead-lag blocks coefficient (KL11). Typical Value = 1.
kl17
Low band first lead-lag blocks coefficient (KL17). Typical Value = 1.
kl2
Low band differential filter gain (KL2). Typical Value = 66.
omeganh1
Notch filter 1 (high-frequency band): filter frequency (omegani).
omeganh2
Notch filter 2 (high-frequency band): filter frequency (omegani).
omeganl1
Notch filter 1 (low-frequency band): filter frequency (omegani).
omeganl2
Notch filter 2 (low-frequency band): filter frequency (omegani).
th1
High band time constant (TH1). Typical Value = 0.01513.
th10
High band time constant (TH10). Typical Value = 0.
th11
High band time constant (TH11). Typical Value = 0.
th12
High band time constant (TH12). Typical Value = 0.
th2
High band time constant (TH2). Typical Value = 0.01816.
th3
High band time constant (TH3). Typical Value = 0.
th4
High band time constant (TH4). Typical Value = 0.
th5
High band time constant (TH5). Typical Value = 0.
th6
High band time constant (TH6). Typical Value = 0.
th7
High band time constant (TH7). Typical Value = 0.01816.
th8
High band time constant (TH8). Typical Value = 0.02179.
th9
High band time constant (TH9). Typical Value = 0.
ti1
Intermediate band time constant (TI1). Typical Value = 0.173.
ti10
Intermediate band time constant (TI11). Typical Value = 0.
ti11
Intermediate band time constant (TI11). Typical Value = 0.
ti12
Intermediate band time constant (TI2). Typical Value = 0.
ti2
Intermediate band time constant (TI2). Typical Value = 0.2075.
ti3
Intermediate band time constant (TI3). Typical Value = 0.
ti4
Intermediate band time constant (TI4). Typical Value = 0.
ti5
Intermediate band time constant (TI5). Typical Value = 0.
ti6
Intermediate band time constant (TI6). Typical Value = 0.
ti7
Intermediate band time constant (TI7). Typical Value = 0.2075.
ti8
Intermediate band time constant (TI8). Typical Value = 0.2491.
ti9
Intermediate band time constant (TI9). Typical Value = 0.
tl1
Low band time constant (TL1). Typical Value = 1.73.
tl10
Low band time constant (TL10). Typical Value = 0.
tl11
Low band time constant (TL11). Typical Value = 0.
tl12
Low band time constant (TL12). Typical Value = 0.
tl2
Low band time constant (TL2). Typical Value = 2.075.
tl3
Low band time constant (TL3). Typical Value = 0.
tl4
Low band time constant (TL4). Typical Value = 0.
tl5
Low band time constant (TL5). Typical Value = 0.
tl6
Low band time constant (TL6). Typical Value = 0.
tl7
Low band time constant (TL7). Typical Value = 2.075.
tl8
Low band time constant (TL8). Typical Value = 2.491.
tl9
Low band time constant (TL9). Typical Value = 0.
vhmax
High band output maximum limit (VHmax). Typical Value = 0.6.
vhmin
High band output minimum limit (VHmin). Typical Value = -0.6.
vimax
Intermediate band output maximum limit (VImax). Typical Value = 0.6.
vimin
Intermediate band output minimum limit (VImin). Typical Value = -0.6.
vlmax
Low band output maximum limit (VLmax). Typical Value = 0.075.
vlmin
Low band output minimum limit (VLmin). Typical Value = -0.075.
vstmax
PSS output maximum limit (VSTmax). Typical Value = 0.15.
vstmin
PSS output minimum limit (VSTmin). Typical Value = -0.15.
Pss1
Italian PSS - three input PSS (speed, frequency, power).
kw
Shaft speed power input gain (KW). Typical Value = 0.
kf
Frequency power input gain (KF). Typical Value = 5.
kpe
Electric power input gain (KPE). Typical Value = 0.3.
pmin
Minimum power PSS enabling (PMIN). Typical Value = 0.25.
ks
PSS gain (KS). Typical Value = 1.
vsmn
Stabilizer output max limit (VSMN). Typical Value = -0.06.
vsmx
Stabilizer output min limit (VSMX). Typical Value = 0.06.
tpe
Electric power filter time constant (TPE). Typical Value = 0.05.
t5
Washout (T5). Typical Value = 3.5.
t6
Filter time constant (T6). Typical Value = 0.
t7
Lead/lag time constant (T7). Typical Value = 0.
t8
Lead/lag time constant (T8). Typical Value = 0.
t9
Lead/lag time constant (T9). Typical Value = 0.
t10
Lead/lag time constant (T10). Typical Value = 0.
vadat
Signal selector (VadAt).
true = closed (Generator Power is greater than Pmin)
false = open (Pe is smaller than Pmin).
Typical Value = true.
Pss1A
Single input power system stabilizer. It is a modified version in order to allow representation of various vendors' implementations on PSS type 1A.
inputSignalType
Type of input signal.
a1
Notch filter parameter (A1).
a2
Notch filter parameter (A2).
t1
Lead/lag time constant (T1).
t2
Lead/lag time constant (T2).
t3
Lead/lag time constant (T3).
t4
Lead/lag time constant (T4).
t5
Washout time constant (T5).
t6
Transducer time constant (T6).
ks
Stabilizer gain (Ks).
vrmax
Maximum stabilizer output (Vrmax).
vrmin
Minimum stabilizer output (Vrmin).
vcu
Stabilizer input cutoff threshold (Vcu).
vcl
Stabilizer input cutoff threshold (Vcl).
a3
Notch filter parameter (A3).
a4
Notch filter parameter (A4).
a5
Notch filter parameter (A5).
a6
Notch filter parameter (A6).
a7
Notch filter parameter (A7).
a8
Notch filter parameter (A8).
kd
Selector (Kd).
true = e-sTdelay used
false = e-sTdelay not used.
tdelay
Time constant (Tdelay).
Pss2B
Modified IEEE PSS2B Model. Extra lead/lag (or rate) block added at end (up to 4 lead/lags total).
inputSignal1Type
Type of input signal #1. Typical Value = rotorSpeed.
inputSignal2Type
Type of input signal #2. Typical Value = generatorElectricalPower.
vsi1max
Input signal #1 max limit (Vsi1max). Typical Value = 2.
vsi1min
Input signal #1 min limit (Vsi1min). Typical Value = -2.
tw1
First washout on signal #1 (Tw1). Typical Value = 2.
tw2
Second washout on signal #1 (Tw2). Typical Value = 2.
vsi2max
Input signal #2 max limit (Vsi2max). Typical Value = 2.
vsi2min
Input signal #2 min limit (Vsi2min). Typical Value = -2.
tw3
First washout on signal #2 (Tw3). Typical Value = 2.
tw4
Second washout on signal #2 (Tw4). Typical Value = 0.
t1
Lead/lag time constant (T1). Typical Value = 0.12.
t2
Lead/lag time constant (T2). Typical Value = 0.02.
t3
Lead/lag time constant (T3). Typical Value = 0.3.
t4
Lead/lag time constant (T4). Typical Value = 0.02.
t6
Time constant on signal #1 (T6). Typical Value = 0.
t7
Time constant on signal #2 (T7). Typical Value = 2.
t8
Lead of ramp tracking filter (T8). Typical Value = 0.2.
t9
Lag of ramp tracking filter (T9). Typical Value = 0.1.
t10
Lead/lag time constant (T10). Typical Value = 0.
t11
Lead/lag time constant (T11). Typical Value = 0.
ks1
Stabilizer gain (Ks1). Typical Value = 12.
ks2
Gain on signal #2 (Ks2). Typical Value = 0.2.
ks3
Gain on signal #2 input before ramp-tracking filter (Ks3). Typical Value = 1.
ks4
Gain on signal #2 input after ramp-tracking filter (Ks4). Typical Value = 1.
n
Order of ramp tracking filter (N). Typical Value = 1.
m
Denominator order of ramp tracking filter (M). Typical Value = 5.
vstmax
Stabilizer output max limit (Vstmax). Typical Value = 0.1.
vstmin
Stabilizer output min limit (Vstmin). Typical Value = -0.1.
a
Numerator constant (a). Typical Value = 1.
ta
Lead constant (Ta). Typical Value = 0.
tb
Lag time constant (Tb). Typical Value = 0.
Pss2ST
PTI Microprocessor-Based Stabilizer type 1.
inputSignal1Type
Type of input signal #1. Typical Value = rotorAngularFrequencyDeviation.
inputSignal2Type
Type of input signal #2. Typical Value = generatorElectricalPower.
k1
Gain (K1).
k2
Gain (K2).
t1
Time constant (T1).
t2
Time constant (T2).
t3
Time constant (T3).
t4
Time constant (T4).
t5
Time constant (T5).
t6
Time constant (T6).
t7
Time constant (T7).
t8
Time constant (T8).
t9
Time constant (T9).
t10
Time constant (T10).
lsmax
Limiter (Lsmax).
lsmin
Limiter (Lsmin).
vcu
Cutoff limiter (Vcu).
vcl
Cutoff limiter (Vcl).
Pss5
Italian PSS - Detailed PSS.
kpe
Electric power input gain (KPE). Typical Value = 0.3.
kf
Frequency/shaft speed input gain (KF). Typical Value = 5.
isfreq
Selector for Frequency/shaft speed input (IsFreq).
true = speed
false = frequency.
Typical Value = true.
kpss
PSS gain (KPSS). Typical Value = 1.
ctw2
Selector for Second washout enabling (CTW2).
true = second washout filter is bypassed
false = second washout filter in use.
Typical Value = true.
tw1
First WashOut (Tw1). Typical Value = 3.5.
tw2
Second WashOut (Tw2). Typical Value = 0.
tl1
Lead/lag time constant (TL1). Typical Value = 0.
tl2
Lead/lag time constant (TL2). Typical Value = 0.
tl3
Lead/lag time constant (TL3). Typical Value = 0.
tl4
Lead/lag time constant (TL4). Typical Value = 0.
vsmn
Stabilizer output max limit (VSMN). Typical Value = -0.1.
vsmx
Stabilizer output min limit (VSMX). Typical Value = 0.1.
tpe
Electric power filter time constant (TPE). Typical Value = 0.05.
pmm
Minimum power PSS enabling (Pmn). Typical Value = 0.25.
deadband
Stabilizer output dead band (DeadBand). Typical Value = 0.
vadat
Signal selector (VadAtt).
true = closed (Generator Power is greater than Pmin)
false = open (Pe is smaller than Pmin).
Typical Value = true.
PssELIN2
Power system stabilizer typically associated with ExcELIN2 (though PssIEEE2B or Pss2B can also be used).
ts1
Time constant (Ts1). Typical Value = 0.
ts2
Time constant (Ts2). Typical Value = 1.
ts3
Time constant (Ts3). Typical Value = 1.
ts4
Time constant (Ts4). Typical Value = 0.1.
ts5
Time constant (Ts5). Typical Value = 0.
ts6
Time constant (Ts6). Typical Value = 1.
ks1
Gain (Ks1). Typical Value = 1.
ks2
Gain (Ks2). Typical Value = 0.1.
ppss
Coefficient (p_PSS) (>=0 and <=4). Typical Value = 0.1.
apss
Coefficient (a_PSS). Typical Value = 0.1.
psslim
PSS limiter (psslim). Typical Value = 0.1.
PssPTIST1
PTI Microprocessor-Based Stabilizer type 1.
m
(M). M=2*H. Typical Value = 5.
tf
Time constant (Tf). Typical Value = 0.2.
tp
Time constant (Tp). Typical Value = 0.2.
t1
Time constant (T1). Typical Value = 0.3.
t2
Time constant (T2). Typical Value = 1.
t3
Time constant (T3). Typical Value = 0.2.
t4
Time constant (T4). Typical Value = 0.05.
k
Gain (K). Typical Value = 9.
dtf
Time step frequency calculation (Dtf). Typical Value = 0.025.
dtc
Time step related to activation of controls (Dtc). Typical Value = 0.025.
dtp
Time step active power calculation (Dtp). Typical Value = 0.0125.
PssPTIST3
PTI Microprocessor-Based Stabilizer type 3.
m
(M). M=2*H. Typical Value = 5.
tf
Time constant (Tf). Typical Value = 0.2.
tp
Time constant (Tp). Typical Value = 0.2.
t1
Time constant (T1). Typical Value = 0.3.
t2
Time constant (T2). Typical Value = 1.
t3
Time constant (T3). Typical Value = 0.2.
t4
Time constant (T4). Typical Value = 0.05.
k
Gain (K). Typical Value = 9.
dtf
Time step frequency calculation (0.03 for 50 Hz) (Dtf). Typical Value = 0.025.
dtc
Time step related to activation of controls (0.03 for 50 Hz) (Dtc). Typical Value = 0.025.
dtp
Time step active power calculation (0.015 for 50 Hz) (Dtp). Typical Value = 0.0125.
t5
Time constant (T5).
t6
Time constant (T6).
a0
Filter coefficient (A0).
a1
Limiter (Al).
a2
Filter coefficient (A2).
b0
Filter coefficient (B0).
b1
Filter coefficient (B1).
b2
Filter coefficient (B2).
a3
Filter coefficient (A3).
a4
Filter coefficient (A4).
a5
Filter coefficient (A5).
b3
Filter coefficient (B3).
b4
Filter coefficient (B4).
b5
Filter coefficient (B5).
athres
Threshold value above which output averaging will be bypassed (Athres). Typical Value = 0.005.
dl
Limiter (Dl).
al
Limiter (Al).
lthres
Threshold value (Lthres).
pmin
(Pmin).
isw
Digital/analog output switch (Isw).
true = produce analog output
false = convert to digital output, using tap selection table.
nav
Number of control outputs to average (Nav) (1 <= Nav <= 16). Typical Value = 4.
ncl
Number of counts at limit to active limit function (Ncl) (>0).
ncr
Number of counts until reset after limit function is triggered (Ncr).
PssSB4
Power sensitive stabilizer model.
tt
Time constant (Tt).
kx
Gain (Kx).
tx2
Time constant (Tx2).
ta
Time constant (Ta).
tx1
Reset time constant (Tx1).
tb
Time constant (Tb).
tc
Time constant (Tc).
td
Time constant (Td).
te
Time constant (Te).
vsmax
Limiter (Vsmax).
vsmin
Limiter (Vsmin).
PssSH
Model for Siemens “H infinity” power system stabilizer with generator electrical power input.
k
Main gain (K). Typical Value = 1.
k0
Gain 0 (K0). Typical Value = 0.012.
k1
Gain 1 (K1). Typical Value = 0.488.
k2
Gain 2 (K2). Typical Value = 0.064.
k3
Gain 3 (K3). Typical Value = 0.224.
k4
Gain 4 (K4). Typical Value = 0.1.
td
Input time constant (Td). Typical Value = 10.
t1
Time constant 1 (T1). Typical Value = 0.076.
t2
Time constant 2 (T2). Typical Value = 0.086.
t3
Time constant 3 (T3). Typical Value = 1.068.
t4
Time constant 4 (T4). Typical Value = 1.913.
vsmax
Output maximum limit (Vsmax). Typical Value = 0.1.
vsmin
Output minimum limit (Vsmin). Typical Value = -0.1.
PssSK
PSS Slovakian type – three inputs.
k1
Gain P (K1). Typical Value = -0.3.
k2
Gain fe (K2). Typical Value = -0.15.
k3
Gain If (K3). Typical Value = 10.
t1
Denominator time constant (T1). Typical Value = 0.3.
t2
Filter time constant (T2). Typical Value = 0.35.
t3
Denominator time constant (T3). Typical Value = 0.22.
t4
Filter time constant (T4). Typical Value = 0.02.
t5
Denominator time constant (T5). Typical Value = 0.02.
t6
Filter time constant (T6). Typical Value = 0.02.
vsmax
Stabilizer output max limit (Vsmax). Typical Value = 0.4.
vsmin
Stabilizer output min limit (Vsmin). Typical Value = -0.4.
PssWECC
Dual input Power System Stabilizer, based on IEEE type 2, with modified output limiter defined by WECC (Western Electricity Coordinating Council, USA).
inputSignal1Type
Type of input signal #1.
inputSignal2Type
Type of input signal #2.
k1
Input signal 1 gain (K1).
t1
Input signal 1 transducer time constant (T1).
k2
Input signal 2 gain (K2).
t2
Input signal 2 transducer time constant (T2).
t3
Stabilizer washout time constant (T3).
t4
Stabilizer washout time lag constant (T4) (>0).
t5
Lead time constant (T5).
t6
Lag time constant (T6).
t7
Lead time constant (T7).
t8
Lag time constant (T8).
t10
Lag time constant (T10).
t9
Lead time constant (T9).
vsmax
Maximum output signal (Vsmax).
vsmin
Minimum output signal (Vsmin).
vcu
Maximum value for voltage compensator output (VCU).
vcl
Minimum value for voltage compensator output (VCL).
DiscontinuousExcitationControlDynamics
In some particular system configurations, continuous excitation control with terminal voltage and power system stabilizing regulator input signals does not ensure that the potential of the excitation system for improving system stability is fully exploited. For these situations, discontinuous excitation control signals may be employed to enhance stability following large transient disturbances.
For additional information please refer to IEEE Standard 421.5-2005, Section 12.
DiscontinuousExcitationControlDynamics
Discontinuous excitation control function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
DiscExcContIEEEDEC1A
The class represents IEEE Type DEC1A discontinuous excitation control model that boosts generator excitation to a level higher than that demanded by the voltage regulator and stabilizer immediately following a system fault.
Reference: IEEE Standard 421.5-2005 Section 12.2.
vtlmt
Voltage reference (VTLMT). Typical Value = 1.1.
vomax
Limiter (VOMAX). Typical Value = 0.3.
vomin
Limiter (VOMIN). Typical Value = 0.1.
ketl
Terminal voltage limiter gain (KETL). Typical Value = 47.
vtc
Terminal voltage level reference (VTC). Typical Value = 0.95.
val
Regulator voltage reference (VAL). Typical Value = 5.5.
esc
Speed change reference (ESC). Typical Value = 0.0015.
kan
Discontinuous controller gain (KAN). Typical Value = 400.
tan
Discontinuous controller time constant (TAN). Typical Value = 0.08.
tw5
DEC washout time constant (TW5). Typical Value = 5.
vsmax
Limiter (VSMAX). Typical Value = 0.2.
vsmin
Limiter (VSMIN). Typical Value = -0.066.
td
Time constant (TD). Typical Value = 0.03.
tl1
Time constant (TL1). Typical Value = 0.025.
tl2
Time constant (TL2). Typical Value = 1.25.
vtm
Voltage limits (VTM). Typical Value = 1.13.
vtn
Voltage limits (VTN). Typical Value = 1.12.
vanmax
Limiter for Van (VANMAX).
DiscExcContIEEEDEC2A
The class represents IEEE Type DEC2A model for the discontinuous excitation control. This system provides transient excitation boosting via an open-loop control as initiated by a trigger signal generated remotely.
Reference: IEEE Standard 421.5-2005 Section 12.3.
vk
Discontinuous controller input reference (VK).
td1
Discontinuous controller time constant (TD1).
td2
Discontinuous controller washout time constant (TD2).
vdmin
Limiter (VDMIN).
vdmax
Limiter (VDMAX).
DiscExcContIEEEDEC3A
The class represents IEEE Type DEC3A model. In some systems, the stabilizer output is disconnected from the regulator immediately following a severe fault to prevent the stabilizer from competing with action of voltage regulator during the first swing.
Reference: IEEE Standard 421.5-2005 Section 12.4.
vtmin
Terminal undervoltage comparison level (VTMIN).
tdr
Reset time delay (TDR).
PFVArControllerType1Dynamics
Excitation systems for synchronous machines are sometimes supplied with an optional means of automatically adjusting generator output reactive power (VAr) or power factor (PF) to a user-specified value This can be accomplished with either a reactive power or power factor controller or regulator. A reactive power or power factor controller is defined as a PF/VAr controller in IEEE Std 421.1 as “A control function that acts through the reference adjuster to modify the voltage regulator set point to maintain the synchronous machine steady-state power factor or reactive power at a predetermined value.”
For additional information please refer to IEEE Standard 421.5-2005, Section 11.
PFVArControllerType1Dynamics
Power Factor or VAr controller Type I function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
PFVArControllerType1Dynamics
Power Factor or VAr controller Type I model with which this voltage adjuster is associated.
Yes
VoltageAdjusterDynamics
Voltage adjuster model associated with this Power Factor or VA controller Type I model.
VoltageAdjusterDynamics
No
PFVArType1IEEEPFController
The class represents IEEE PF Controller Type 1 which operates by moving the voltage reference directly.
Reference: IEEE Standard 421.5-2005 Section 11.2.
ovex
Overexcitation Flag (OVEX)
true = overexcited
false = underexcited.
tpfc
PF controller time delay (TPFC). Typical Value = 5.
vitmin
Minimum machine terminal current needed to enable pf/var controller (VITMIN).
vpf
Synchronous machine power factor (VPF).
vpfcbw
PF controller dead band (VPFC_BW). Typical Value = 0.05.
vpfref
PF controller reference (VPFREF).
vvtmax
Maximum machine terminal voltage needed for pf/var controller to be enabled (VVTMAX).
vvtmin
Minimum machine terminal voltage needed to enable pf/var controller (VVTMIN).
PFVArType1IEEEVArController
The class represents IEEE VAR Controller Type 1 which operates by moving the voltage reference directly.
Reference: IEEE Standard 421.5-2005 Section 11.3.
tvarc
Var controller time delay (TVARC). Typical Value = 5.
vvar
Synchronous machine power factor (VVAR).
vvarcbw
Var controller dead band (VVARC_BW). Typical Value = 0.02.
vvarref
Var controller reference (VVARREF).
vvtmax
Maximum machine terminal voltage needed for pf/var controller to be enabled (VVTMAX).
vvtmin
Minimum machine terminal voltage needed to enable pf/var controller (VVTMIN).
VoltageAdjusterDynamics
A voltage adjuster is a reference adjuster that uses inputs from a reactive power or power factor controller to modify the voltage regulator set point to maintain the synchronous machine steady-state power factor or reactive power at a predetermined value.
For additional information please refer to IEEE Standard 421.5-2005, Section 11.
VoltageAdjusterDynamics
Voltage adjuster function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
VAdjIEEE
The class represents IEEE Voltage Adjuster which is used to represent the voltage adjuster in either a power factor or var control system.
Reference: IEEE Standard 421.5-2005 Section 11.1.
vadjf
Set high to provide a continuous raise or lower (VADJF).
adjslew
Rate at which output of adjuster changes (ADJ_SLEW). Unit = sec./PU. Typical Value = 300.
vadjmax
Maximum output of the adjuster (VADJMAX). Typical Value = 1.1.
vadjmin
Minimum output of the adjuster (VADJMIN). Typical Value = 0.9.
taon
Time that adjuster pulses are on (TAON). Typical Value = 0.1.
taoff
Time that adjuster pulses are off (TAOFF). Typical Value = 0.5.
PFVArControllerType2Dynamics
A var/pf regulator is defined as “A synchronous machine regulator that functions to maintain the power factor or reactive component of power at a predetermined value.”
For additional information please refer to IEEE Standard 421.5-2005, Section 11.
PFVArControllerType2Dynamics
Power Factor or VAr controller Type II function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
PFVArType2IEEEPFController
The class represents IEEE PF Controller Type 2 which is a summing point type controller and makes up the outside loop of a two-loop system. This controller is implemented as a slow PI type controller. The voltage regulator forms the inner loop and is implemented as a fast controller.
Reference: IEEE Standard 421.5-2005 Section 11.4.
pfref
Power factor reference (PFREF).
vref
Voltage regulator reference (VREF).
vclmt
Maximum output of the pf controller (VCLMT). Typical Value = 0.1.
kp
Proportional gain of the pf controller (KP). Typical Value = 1.
ki
Integral gain of the pf controller (KI). Typical Value = 1.
vs
Generator sensing voltage (VS).
exlon
Overexcitation or under excitation flag (EXLON)
true = 1 (not in the overexcitation or underexcitation state, integral action is active)
false = 0 (in the overexcitation or underexcitation state, so integral action is disabled to allow the limiter to play its role).
PFVArType2IEEEVArController
The class represents IEEE VAR Controller Type 2 which is a summing point type controller. It makes up the outside loop of a two-loop system. This controller is implemented as a slow PI type controller, and the voltage regulator forms the inner loop and is implemented as a fast controller.
Reference: IEEE Standard 421.5-2005 Section 11.5.
qref
Reactive power reference (QREF).
vref
Voltage regulator reference (VREF).
vclmt
Maximum output of the pf controller (VCLMT).
kp
Proportional gain of the pf controller (KP).
ki
Integral gain of the pf controller (KI).
vs
Generator sensing voltage (VS).
exlon
Overexcitation or under excitation flag (EXLON)
true = 1 (not in the overexcitation or underexcitation state, integral action is active)
false = 0 (in the overexcitation or underexcitation state, so integral action is disabled to allow the limiter to play its role).
PFVArType2Common1
Power factor / Reactive power regulator. This model represents the power factor or reactive power controller such as the Basler SCP-250. The controller measures power factor or reactive power (PU on generator rated power) and compares it with the operator's set point.
j
Selector (J).
true = control mode for reactive power
false = control mode for power factor.
kp
Proportional gain (Kp).
ki
Reset gain (Ki).
max
Output limit (max).
ref
Reference value of reactive power or power factor (Ref).
The reference value is initialised by this model. This initialisation may override the value exchanged by this attribute to represent a plant operator's change of the reference setting.
VoltageCompensatorDynamics
Synchronous machine terminal voltage transducer and current compensator models adjust the terminal voltage feedback to the excitation system by adding a quantity that is proportional to the terminal current of the generator. It is linked to a specific generator (synchronous machine).
Several types of compensation are available on most excitation systems. Synchronous machine active and reactive current compensation are the most common. Either reactive droop compensation and/or line-drop compensation may be used, simulating an impedance drop and effectively regulating at some point other than the terminals of the machine. The impedance or range of adjustment and type of compensation should be specified for different types.
Care must be taken to ensure that a consistent pu system is utilized for the compensator parameters and the synchronous machine current base.
For further information see IEEE Standard 421.5-2005, Section 4.
VoltageCompensatorDynamics
Voltage compensator function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
VCompIEEEType1
The class represents the terminal voltage transducer and the load compensator as defined in the IEEE Std 421.5-2005, Section 4. This model is common to all excitation system models described in the IEEE Standard.
Reference: IEEE Standard 421.5-2005 Section 4.
rc
Resistive component of compensation of a generator (Rc).
xc
Reactive component of compensation of a generator (Xc).
tr
Time constant which is used for the combined voltage sensing and compensation signal (Tr).
VCompIEEEType2
The class represents the terminal voltage transducer and the load compensator as defined in the IEEE Std 421.5-2005, Section 4. This model is designed to cover the following types of compensation:
- reactive droop
- transformer-drop or line-drop compensation
- reactive differential compensation known also as cross-current compensation.
Reference: IEEE Standard 421.5-2005, Section 4.
tr
Time constant which is used for the combined voltage sensing and compensation signal (Tr).
VcompIEEEType2
The standard IEEE Type 2 voltage compensator of this compensation.
Yes
GenICompensationForGenJ
Compensation of this voltage compensator's generator for current flow out of another generator.
GenICompensationForGenJ
No
GenICompensationForGenJ
This class provides the resistive and reactive components of compensation for the generator associated with the IEEE Type 2 voltage compensator for current flow out of one of the other generators in the interconnection.
rcij
Resistive component of compensation of generator associated with this IEEE Type 2 voltage compensator for current flow out of another generator (Rcij).
xcij
Reactive component of compensation of generator associated with this IEEE Type 2 voltage compensator for current flow out of another generator (Xcij).
WindDynamics
Wind turbines are generally divided into 4 types, which are currently significant in power systems. The 4 types have the following characteristics:
- Type 1: Wind turbine with directly grid connected asynchronous generator with fixed rotor resistance (typically squirrel cage)
- Type 2: Wind turbine with directly grid connected asynchronous generator with variable rotor resistance
- Type 3: Wind turbines with doubly-fed asynchronous generators (directly connected stator and rotor connected through power converter)
- Type 4: Wind turbines connected fully through a power converter.
Models included in this package are according to IEC 61400-27-1.
WindAeroConstIEC
The constant aerodynamic torque model assumes that the aerodynamic torque is constant.
Reference: IEC Standard 61400-27-1 Section 6.6.1.1.
WindGenTurbineType1IEC
Wind turbine type 1 model with which this wind aerodynamic model is associated.
No
WindAeroConstIEC
Wind aerodynamic model associated with this wind turbine type 1 model.
WindAeroConstIEC
Yes
WindAeroLinearIEC
The linearised aerodynamic model.
Reference: IEC Standard 614000-27-1 Section 6.6.1.2.
dpomega
Partial derivative of aerodynamic power with respect to changes in WTR speed (dpomega). It is case dependent parameter.
dptheta
Partial derivative of aerodynamic power with respect to changes in pitch angle (dptheta). It is case dependent parameter.
omegazero
Rotor speed if the wind turbine is not derated (omega0). It is case dependent parameter.
pavail
Available aerodynamic power (pavail). It is case dependent parameter.
thetazero
Pitch angle if the wind turbine is not derated (theta0). It is case dependent parameter.
WindGenTurbineType3IEC
Wind generator type 3 model with which this wind aerodynamic model is associated.
No
WindAeroLinearIEC
Wind aerodynamic model associated with this wind generator type 3 model.
WindAeroLinearIEC
Yes
WindContCurrLimIEC
Current limitation model. The current limitation model combines the physical limits.
Reference: IEC Standard 61400-27-1 Section 6.6.5.7.
imax
Maximum continuous current at the wind turbine terminals (imax). It is type dependent parameter.
imaxdip
Maximum current during voltage dip at the wind turbine terminals (imax,dip). It is project dependent parameter.
mdfslim
Limitation of type 3 stator current (MDFSLim):
- false=0: total current limitation,
- true=1: stator current limitation).
It is type dependent parameter.
mqpri
Prioritisation of q control during LVRT (Mqpri):
- true = 1: reactive power priority,
- false = 0: active power priority.
It is project dependent parameter.
tufilt
Voltage measurement filter time constant (Tufilt). It is type dependent parameter.
WindTurbineType3or4IEC
Wind turbine type 3 or 4 model with which this wind control current limitation model is associated.
No
WindContCurrLimIEC
Wind control current limitation model associated with this wind turbine type 3 or 4 model.
WindContCurrLimIEC
Yes
WindDynamicsLookupTable
The current control limitation model with which this wind dynamics lookup table is associated.
No
WindContCurrLimIEC
The wind dynamics lookup table associated with this current control limitation model.
WindContCurrLimIEC
Yes
WindContPitchAngleIEC
Pitch angle control model.
Reference: IEC Standard 61400-27-1 Section 6.6.5.8.
dthetamax
Maximum pitch positive ramp rate (dthetamax). It is type dependent parameter. Unit = degrees/sec.
dthetamin
Maximum pitch negative ramp rate (dthetamin). It is type dependent parameter. Unit = degrees/sec.
kic
Power PI controller integration gain (KIc). It is type dependent parameter.
kiomega
Speed PI controller integration gain (KIomega). It is type dependent parameter.
kpc
Power PI controller proportional gain (KPc). It is type dependent parameter.
kpomega
Speed PI controller proportional gain (KPomega). It is type dependent parameter.
kpx
Pitch cross coupling gain (KPX). It is type dependent parameter.
thetamax
Maximum pitch angle (thetamax). It is type dependent parameter.
thetamin
Minimum pitch angle (thetamin). It is type dependent parameter.
ttheta
Pitch time constant (ttheta). It is type dependent parameter.
WindGenTurbineType3IEC
Wind turbine type 3 model with which this pitch control model is associated.
No
WindContPitchAngleIEC
Wind control pitch angle model associated with this wind turbine type 3.
WindContPitchAngleIEC
Yes
WindContPType3IEC
P control model Type 3.
Reference: IEC Standard 61400-27-1 Section 6.6.5.3.
dpmax
Maximum wind turbine power ramp rate (dpmax). It is project dependent parameter.
dtrisemaxlvrt
Limitation of torque rise rate during LVRT for S1 (dTrisemaxLVRT). It is project dependent parameter.
kdtd
Gain for active drive train damping (KDTD). It is type dependent parameter.
kip
PI controller integration parameter (KIp). It is type dependent parameter.
kpp
PI controller proportional gain (KPp). It is type dependent parameter.
mplvrt
Enable LVRT power control mode (MpLVRT).
true = 1: voltage control
false = 0: reactive power control.
It is project dependent parameter.
omegaoffset
Offset to reference value that limits controller action during rotor speed changes (omegaoffset). It is case dependent parameter.
pdtdmax
Maximum active drive train damping power (pDTDmax). It is type dependent parameter.
rramp
Ramp limitation of torque, required in some grid codes (Rramp). It is project dependent parameter.
tdvs
Time delay after deep voltage sags (TDVS). It is project dependent parameter.
temin
Minimum electrical generator torque (Temin). It is type dependent parameter.
tomegafilt
Filter time constant for generator speed measurement (Tomegafilt). It is type dependent parameter.
tpfilt
Filter time constant for power measurement (Tpfilt). It is type dependent parameter.
tpord
Time constant in power order lag (Tpord). It is type dependent parameter.
tufilt
Filter time constant for voltage measurement (Tufilt). It is type dependent parameter.
tuscale
Voltage scaling factor of reset-torque (Tuscale). It is project dependent parameter.
twref
Time constant in speed reference filter (Tomega,ref). It is type dependent parameter.
udvs
Voltage limit for hold LVRT status after deep voltage sags (uDVS). It is project dependent parameter.
updip
Voltage dip threshold for P-control (uPdip). Part of turbine control, often different (e.g 0.8) from converter thresholds. It is project dependent parameter.
wdtd
Active drive train damping frequency (omegaDTD). It can be calculated from two mass model parameters. It is type dependent parameter.
zeta
Coefficient for active drive train damping (zeta). It is type dependent parameter.
WindGenTurbineType3IEC
Wind turbine type 3 model with which this Wind control P type 3 model is associated.
No
WindContPType3IEC
Wind control P type 3 model associated with this wind turbine type 3 model.
WindContPType3IEC
Yes
WindDynamicsLookupTable
The P control type 3 model with which this wind dynamics lookup table is associated.
No
WindContPType3IEC
The wind dynamics lookup table associated with this P control type 3 model.
WindContPType3IEC
Yes
WindContPType4aIEC
P control model Type 4A.
Reference: IEC Standard 61400-27-1 Section 6.6.5.4.
dpmax
Maximum wind turbine power ramp rate (dpmax). It is project dependent parameter.
tpord
Time constant in power order lag (Tpord). It is type dependent parameter.
tufilt
Voltage measurement filter time constant (Tufilt). It is type dependent parameter.
WindTurbineType4aIEC
Wind turbine type 4A model with which this wind control P type 4A model is associated.
No
WindContPType4aIEC
Wind control P type 4A model associated with this wind turbine type 4A model.
WindContPType4aIEC
Yes
WindContPType4bIEC
P control model Type 4B.
Reference: IEC Standard 61400-27-1 Section 6.6.5.5.
dpmax
Maximum wind turbine power ramp rate (dpmax). It is project dependent parameter.
tpaero
Time constant in aerodynamic power response (Tpaero). It is type dependent parameter.
tpord
Time constant in power order lag (Tpord). It is type dependent parameter.
tufilt
Voltage measurement filter time constant (Tufilt). It is type dependent parameter.
WindTurbineType4bIEC
Wind turbine type 4B model with which this wind control P type 4B model is associated.
No
WindContPType4bIEC
Wind control P type 4B model associated with this wind turbine type 4B model.
WindContPType4bIEC
Yes
WindContQIEC
Q control model.
Reference: IEC Standard 61400-27-1 Section 6.6.5.6.
iqh1
Maximum reactive current injection during dip (iqh1). It is type dependent parameter.
iqmax
Maximum reactive current injection (iqmax). It is type dependent parameter.
iqmin
Minimum reactive current injection (iqmin). It is type dependent parameter.
iqpost
Post fault reactive current injection (iqpost). It is project dependent parameter.
kiq
Reactive power PI controller integration gain (KI,q). It is type dependent parameter.
kiu
Voltage PI controller integration gain (KI,u). It is type dependent parameter.
kpq
Reactive power PI controller proportional gain (KP,q). It is type dependent parameter.
kpu
Voltage PI controller proportional gain (KP,u). It is type dependent parameter.
kqv
Voltage scaling factor for LVRT current (Kqv). It is project dependent parameter.
qmax
Maximum reactive power (qmax). It is type dependent parameter.
qmin
Minimum reactive power (qmin). It is type dependent parameter.
rdroop
Resistive component of voltage drop impedance (rdroop). It is project dependent parameter.
tiq
Time constant in reactive current lag (Tiq). It is type dependent parameter.
tpfilt
Power measurement filter time constant (Tpfilt). It is type dependent parameter.
tpost
Length of time period where post fault reactive power is injected (Tpost). It is project dependent parameter.
tqord
Time constant in reactive power order lag (Tqord). It is type dependent parameter.
tufilt
Voltage measurement filter time constant (Tufilt). It is type dependent parameter.
udb1
Voltage dead band lower limit (udb1). It is type dependent parameter.
udb2
Voltage dead band upper limit (udb2). It is type dependent parameter.
umax
Maximum voltage in voltage PI controller integral term (umax). It is type dependent parameter.
umin
Minimum voltage in voltage PI controller integral term (umin). It is type dependent parameter.
uqdip
Voltage threshold for LVRT detection in q control (uqdip). It is type dependent parameter.
uref0
User defined bias in voltage reference (uref0), used when MqG = MG,u. It is case dependent parameter.
windLVRTQcontrolModesType
Types of LVRT Q control modes (MqLVRT). It is project dependent parameter.
WindLVRTQcontrolModesKind
LVRT Q control modes MqLVRT.
mode1
Voltage dependent reactive current injection (MLVRT,1).
mode2
Reactive current injection controlled as the pre-fault value plus an additional voltage dependent reactive current injection (MLVRT,2).
mode3
Reactive current injection controlled as the pre-fault value plus an additional voltage dependent reactive current injection during fault, and as the pre-fault value plus an additional constant reactive current injection post fault (MLVRT,3).
windQcontrolModesType
Types of general wind turbine Q control modes (MqG). It is project dependent parameter.
WindQcontrolModesKind
General wind turbine Q control modes MqG.
voltage
Voltage control (MG,u).
reactivePower
Reactive power control (MG,q).
openLoopReactivePower
Open loop reactive power control (only used with closed loop at plant level) (MG,qol).
powerFactor
Power factor control (MG,pf).
xdroop
Inductive component of voltage drop impedance (xdroop). It is project dependent parameter.
WindTurbineType3or4IEC
Wind turbine type 3 or 4 model with which this reactive control mode is associated.
No
WIndContQIEC
Wind control Q model associated with this wind turbine type 3 or 4 model.
WIndContQIEC
Yes
WindContRotorRIEC
Rotor resistance control model.
Reference: IEC Standard 61400-27-1 Section 6.6.5.2.
kirr
Integral gain in rotor resistance PI controller (KIrr). It is type dependent parameter.
komegafilt
Filter gain for generator speed measurement (Komegafilt). It is type dependent parameter.
kpfilt
Filter gain for power measurement (Kpfilt). It is type dependent parameter.
kprr
Proportional gain in rotor resistance PI controller (KPrr). It is type dependent parameter.
rmax
Maximum rotor resistance (rmax). It is type dependent parameter.
rmin
Minimum rotor resistance (rmin). It is type dependent parameter.
tomegafilt
Filter time constant for generator speed measurement (Tomegafilt). It is type dependent parameter.
tpfilt
Filter time constant for power measurement (Tpfilt). It is type dependent parameter.
WindContRotorRIEC
The rotor resistance control model with which this wind dynamics lookup table is associated.
Yes
WindDynamicsLookupTable
The wind dynamics lookup table associated with this rotor resistance control model.
WindDynamicsLookupTable
No
WindGenTurbineType2IEC
Wind turbine type 2 model with whitch this wind control rotor resistance model is associated.
No
WindContRotorRIEC
Wind control rotor resistance model associated with wind turbine type 2 model.
WindContRotorRIEC
Yes
WindDynamicsLookupTable
The class models a look up table for the purpose of wind standard models.
input
Input value (x) for the lookup table function.
lookupTableFunctionType
Type of the lookup table function.
WindLookupTableFunctionKind
Function of the lookup table.
fpslip
Power versus slip lookup table (fpslip()). It is used for rotor resistance control model, IEC 61400-27-1, section 6.6.5.2.
fpomega
Power vs. speed lookup table (fpomega()). It is used for P control model type 3, IEC 61400-27-1, section 6.6.5.3.
ipvdl
Lookup table for voltage dependency of active current limits (ipVDL()). It is used for current limitation model, IEC 61400-27-1, section 6.6.5.7.
iqvdl
Lookup table for voltage dependency of reactive current limits (iqVDL()). It is used for current limitation model, IEC 61400-27-1, section 6.6.5.7.
fdpf
Power vs. frequency lookup table (fdpf()). It is used for wind power plant frequency and active power control model, IEC 61400-27-1, Annex E.
output
Output value (y) for the lookup table function.
sequence
Sequence numbers of the pairs of the input (x) and the output (y) of the lookup table function.
WindDynamicsLookupTable
The frequency and active power wind plant control model with which this wind dynamics lookup table is associated.
No
WindPlantFreqPcontrolIEC
The wind dynamics lookup table associated with this frequency and active power wind plant model.
WindPlantFreqPcontrolIEC
Yes
WindGenTurbineType1IEC
Wind turbine IEC Type 1.
Reference: IEC Standard 61400-27-1, section 6.5.2.
WindGenTurbineType2IEC
Wind turbine IEC Type 2.
Reference: IEC Standard 61400-27-1, section 6.5.3.
WindGenTurbineType2IEC
Wind turbine type 2 model with which this Pitch control emulator model is associated.
No
WindPitchContEmulIEC
Pitch control emulator model associated with this wind turbine type 2 model.
WindPitchContEmulIEC
Yes
WindGenTurbineType3aIEC
IEC Type 3A generator set model.
Reference: IEC Standard 61400-27-1 Section 6.6.3.2.
kpc
Current PI controller proportional gain (KPc). It is type dependent parameter.
xs
Electromagnetic transient reactance (xS). It is type dependent parameter.
tic
Current PI controller integration time constant (TIc). It is type dependent parameter.
WindGenTurbineType3bIEC
IEC Type 3B generator set model.
Reference: IEC Standard 61400-27-1 Section 6.6.3.3.
fducw
Crowbar duration versus voltage variation look-up table (fduCW()). It is case dependent parameter.
tg
Current generation Time constant (Tg). It is type dependent parameter.
two
Time constant for crowbar washout filter (Two). It is case dependent parameter.
mwtcwp
Crowbar control mode (MWTcwp).
- true = 1 in the model
- false = 0 in the model.
The parameter is case dependent parameter.
xs
Electromagnetic transient reactance (xS). It is type dependent parameter.
WindGenTurbineType3IEC
Generator model for wind turbines of IEC type 3A and 3B.
abstract
dipmax
Maximum active current ramp rate (dipmax). It is project dependent parameter.
diqmax
Maximum reactive current ramp rate (diqmax). It is project dependent parameter.
WindGenTurbineType3IEC
Wind turbine Type 3 model with which this wind mechanical model is associated.
No
WindMechIEC
Wind mechanical model associated with this wind turbine Type 3 model.
WindMechIEC
Yes
WindGenType4IEC
IEC Type 4 generator set model.
Reference: IEC Standard 61400-27-1 Section 6.6.3.4.
abstract
dipmax
Maximum active current ramp rate (dipmax). It is project dependent parameter.
diqmin
Minimum reactive current ramp rate (diqmin). It is case dependent parameter.
diqmax
Maximum reactive current ramp rate (diqmax). It is project dependent parameter.
tg
Time constant (Tg). It is type dependent parameter.
WindMechIEC
Two mass model.
Reference: IEC Standard 61400-27-1 Section 6.6.2.1.
cdrt
Drive train damping (cdrt). It is type dependent parameter.
hgen
Inertia constant of generator (Hgen). It is type dependent parameter.
hwtr
Inertia constant of wind turbine rotor (HWTR). It is type dependent parameter.
kdrt
Drive train stiffness (kdrt). It is type dependent parameter.
WindTurbineType4bIEC
Wind turbine type 4B model with which this wind mechanical model is associated.
No
WindMechIEC
Wind mechanical model associated with this wind turbine Type 4B model.
WindMechIEC
Yes
WindTurbineType1or2IEC
Wind generator type 1 or 2 model with which this wind mechanical model is associated.
No
WindMechIEC
Wind mechanical model associated with this wind generator type 1 or 2 model.
WindMechIEC
Yes
WindPitchContEmulIEC
Pitch control emulator model.
Reference: IEC Standard 61400-27-1 Section 6.6.5.1.
kdroop
Power error gain (Kdroop). It is case dependent parameter.
kipce
Pitch control emulator integral constant (KI,pce). It is type dependent parameter.
komegaaero
Aerodynamic power change vs. omegaWTR change (Komegaaero). It is case dependent parameter.
kppce
Pitch control emulator proportional constant (KP,pce). It is type dependent parameter.
omegaref
Rotor speed in initial steady state (omegaref). It is case dependent parameter.
pimax
Maximum steady state power (pimax). It is case dependent parameter.
pimin
Minimum steady state power (pimin). It is case dependent parameter.
t1
First time constant in pitch control lag (T1). It is type dependent parameter.
t2
Second time constant in pitch control lag (T2). It is type dependent parameter.
tpe
Time constant in generator air gap power lag (Tpe). It is type dependent parameter.
WindPlantDynamics
Parent class supporting relationships to wind turbines Type 3 and 4 and wind plant IEC and user defined wind plants including their control models.
abstract
WindTurbineType3or4Dynamics
The wind turbine type 3 or 4 associated with this wind plant.
No
WindPlantDynamics
The wind plant with which the wind turbines type 3 or 4 are associated.
WindPlantDynamics
Yes
WindPlantFreqPcontrolIEC
Frequency and active power controller model.
Reference: IEC Standard 61400-27-1 Annex E.
dprefmax
Maximum ramp rate of pWTref request from the plant controller to the wind turbines (dprefmax). It is project dependent parameter.
dprefmin
Minimum (negative) ramp rate of pWTref request from the plant controller to the wind turbines (dprefmin). It is project dependent parameter.
kiwpp
Plant P controller integral gain (KIWPp). It is type dependent parameter.
kpwpp
Plant P controller proportional gain (KPWPp). It is type dependent parameter.
prefmax
Maximum pWTref request from the plant controller to the wind turbines (prefmax). It is type dependent parameter.
prefmin
Minimum pWTref request from the plant controller to the wind turbines (prefmin). It is type dependent parameter.
tpft
Lead time constant in reference value transfer function (Tpft). It is type dependent parameter.
tpfv
Lag time constant in reference value transfer function (Tpfv). It is type dependent parameter.
twpffilt
Filter time constant for frequency measurement (TWPffilt). It is type dependent parameter.
twppfilt
Filter time constant for active power measurement (TWPpfilt). It is type dependent parameter.
WindPlantIEC
Wind plant model with which this wind plant frequency and active power control is associated.
No
WindPlantFreqPcontrolIEC
Wind plant frequency and active power control model associated with this wind plant.
WindPlantFreqPcontrolIEC
Yes
WindPlantIEC
Simplified IEC type plant level model.
Reference: IEC 61400-27-1, AnnexE.
WindPlantIEC
Wind plant model with which this wind reactive control is associated.
No
WindPlantReactiveControlIEC
Wind plant reactive control model associated with this wind plant.
WindPlantReactiveControlIEC
Yes
WindPlantReactiveControlIEC
Simplified plant voltage and reactive power control model for use with type 3 and type 4 wind turbine models.
Reference: IEC Standard 61400-27-1 Annex E.
kiwpx
Plant Q controller integral gain (KIWPx). It is type dependent parameter.
kpwpx
Plant Q controller proportional gain (KPWPx). It is type dependent parameter.
kwpqu
Plant voltage control droop (KWPqu). It is project dependent parameter.
mwppf
Power factor control modes selector (MWPpf). Used only if mwpu is set to false.
true = 1: power factor control
false = 0: reactive power control.
It is project dependent parameter.
mwpu
Reactive power control modes selector (MWPu).
true = 1: voltage control
false = 0: reactive power control.
It is project dependent parameter.
twppfilt
Filter time constant for active power measurement (TWPpfilt). It is type dependent parameter.
twpqfilt
Filter time constant for reactive power measurement (TWPqfilt). It is type dependent parameter.
twpufilt
Filter time constant for voltage measurement (TWPufilt). It is type dependent parameter.
txft
Lead time constant in reference value transfer function (Txft). It is type dependent parameter.
txfv
Lag time constant in reference value transfer function (Txfv). It is type dependent parameter.
uwpqdip
Voltage threshold for LVRT detection in q control (uWPqdip). It is type dependent parameter.
xrefmax
Maximum xWTref (qWTref or delta uWTref) request from the plant controller (xrefmax). It is project dependent parameter.
xrefmin
Minimum xWTref (qWTref or deltauWTref) request from the plant controller (xrefmin). It is project dependent parameter.
WindProtectionIEC
The grid protection model includes protection against over and under voltage, and against over and under frequency.
Reference: IEC Standard 614000-27-1 Section 6.6.6.
fover
Set of wind turbine over frequency protection levels (fover). It is project dependent parameter.
funder
Set of wind turbine under frequency protection levels (funder). It is project dependent parameter.
tfover
Set of corresponding wind turbine over frequency protection disconnection times (Tfover). It is project dependent parameter.
tfunder
Set of corresponding wind turbine under frequency protection disconnection times (Tfunder). It is project dependent parameter.
tuover
Set of corresponding wind turbine over voltage protection disconnection times (Tuover). It is project dependent parameter.
tuunder
Set of corresponding wind turbine under voltage protection disconnection times (Tuunder). It is project dependent parameter.
uover
Set of wind turbine over voltage protection levels (uover). It is project dependent parameter.
uunder
Set of wind turbine under voltage protection levels (uunder). It is project dependent parameter.
WindTurbineType3or4IEC
Wind generator type 3 or 4 model with which this wind turbine protection model is associated.
No
WindProtectionIEC
Wind turbune protection model associated with this wind generator type 3 or 4 model.
WindProtectionIEC
Yes
WindTurbineType1or2IEC
Wind generator type 1 or 2 model with which this wind turbine protection model is associated.
No
WindProtectionIEC
Wind turbune protection model associated with this wind generator type 1 or 2 model.
WindProtectionIEC
Yes
WindTurbineType1or2Dynamics
Parent class supporting relationships to wind turbines Type 1 and 2 and their control models.
abstract
WindTurbineType1or2IEC
Generator model for wind turbine of IEC Type 1 or Type 2 is a standard asynchronous generator model.
Reference: IEC Standard 614000-27-1 Section 6.6.3.1.
abstract
WindTurbineType3or4Dynamics
Parent class supporting relationships to wind turbines Type 3 and 4 and wind plant including their control models.
abstract
WindTurbineType3or4IEC
Parent class supporting relationships to IEC wind turbines Type 3 and 4 and wind plant including their control models.
abstract
WindTurbineType4aIEC
Wind turbine IEC Type 4A.
Reference: IEC Standard 61400-27-1, section 6.5.5.2.
WindTurbineType4bIEC
Wind turbine IEC Type 4A.
Reference: IEC Standard 61400-27-1, section 6.5.5.3.
LoadDynamics
Dynamic load models are used to represent the dynamic real and reactive load behaviour of a load from the static power flow model.
Dynamic load models can be defined as applying either to a single load (energy consumer) or to a group of energy consumers.
Large industrial motors or groups of similar motors may be represented by individual motor models (synchronous or asynchronous) which are usually represented as generators with negative Pgen in the static (power flow) data.
In the CIM, such individual modelling is handled by child classes of either the SynchronousMachineDynamics or AsynchronousMachineDynamics classes.
LoadComposite
This models combines static load and induction motor load effects.
The dynamics of the motor are simplified by linearizing the induction machine equations.
epvs
Active load-voltage dependence index (static) (Epvs). Typical Value = 0.7.
epfs
Active load-frequency dependence index (static) (Epfs). Typical Value = 1.5.
eqvs
Reactive load-voltage dependence index (static) (Eqvs). Typical Value = 2.
eqfs
Reactive load-frequency dependence index (static) (Eqfs). Typical Value = 0.
epvd
Active load-voltage dependence index (dynamic) (Epvd). Typical Value = 0.7.
epfd
Active load-frequency dependence index (dynamic) (Epfd). Typical Value = 1.5.
eqvd
Reactive load-voltage dependence index (dynamic) (Eqvd). Typical Value = 2.
eqfd
Reactive load-frequency dependence index (dynamic) (Eqfd). Typical Value = 0.
lfrac
Loading factor – ratio of initial P to motor MVA base (Lfrac). Typical Value = 0.8.
h
Inertia constant (H). Typical Value = 2.5.
pfrac
Fraction of constant-power load to be represented by this motor model (Pfrac) (>=0.0 and <=1.0). Typical Value = 0.5.
LoadGenericNonLinear
These load models (known also as generic non-linear dynamic (GNLD) load models) can be used in mid-term and long-term voltage stability simulations (i.e., to study voltage collapse), as they can replace a more detailed representation of aggregate load, including induction motors, thermostatically controlled and static loads.
genericNonLinearLoadModelType
Type of generic non-linear load model.
GenericNonLinearLoadModelKind
Type of generic non-linear load model.
exponentialRecovery
Exponential recovery model.
loadAdaptive
Load adaptive model.
pt
Dynamic portion of active load (PT).
qt
Dynamic portion of reactive load (QT).
tp
Time constant of lag function of active power (TP).
tq
Time constant of lag function of reactive power (TQ).
ls
Steady state voltage index for active power (LS).
lt
Transient voltage index for active power (LT).
bs
Steady state voltage index for reactive power (BS).
bt
Transient voltage index for reactive power (BT).
LoadDynamics
Load whose behaviour is described by reference to a standard model or by definition of a user-defined model.
A standard feature of dynamic load behaviour modelling is the ability to associate the same behaviour to multiple energy consumers by means of a single aggregate load definition. Aggregate loads are used to represent all or part of the real and reactive load from one or more loads in the static (power flow) data. This load is usually the aggregation of many individual load devices and the load model is approximate representation of the aggregate response of the load devices to system disturbances. The load model is always applied to individual bus loads (energy consumers) but a single set of load model parameters can used for all loads in the grouping.
abstract
LoadAggregate
Standard aggregate load model comprised of static and/or dynamic components. A static load model represents the sensitivity of the real and reactive power consumed by the load to the amplitude and frequency of the bus voltage. A dynamic load model can used to represent the aggregate response of the motor components of the load.
LoadAggregate
Aggregate load to which this aggregate static load belongs.
Yes
LoadStatic
Aggregate static load associated with this aggregate load.
LoadStatic
No
LoadAggregate
Aggregate load to which this aggregate motor (dynamic) load belongs.
Yes
LoadMotor
Aggregate motor (dynamic) load associated with this aggregate load.
LoadMotor
No
LoadStatic
General static load model representing the sensitivity of the real and reactive power consumed by the load to the amplitude and frequency of the bus voltage.
staticLoadModelType
Type of static load model. Typical Value = constantZ.
StaticLoadModelKind
Type of static load model.
exponential
Exponential P and Q equations are used and the following attributes are required:
kp1, kp2, kp3, kpf, ep1, ep2, ep3
kq1, kq2, kq3, kqf, eq1, eq2, eq3.
zIP1
ZIP1 P and Q equations are used and the following attributes are required:
kp1, kp2, kp3, kpf
kq1, kq2, kq3, kqf.
zIP2
This model separates the frequency-dependent load (primarily motors) from other load. ZIP2 P and Q equations are used and the following attributes are required:
kp1, kp2, kp3, kq4, kpf
kq1, kq2, kq3, kq4, kqf.
constantZ
The load is represented as a constant impedance. ConstantZ P and Q equations are used and no attributes are required.
kp1
First term voltage coefficient for active power (Kp1). Not used when .staticLoadModelType = constantZ.
kp2
Second term voltage coefficient for active power (Kp2). Not used when .staticLoadModelType = constantZ.
kp3
Third term voltage coefficient for active power (Kp3). Not used when .staticLoadModelType = constantZ.
kp4
Frequency coefficient for active power (Kp4). Must be non-zero when .staticLoadModelType = ZIP2. Not used for all other values of .staticLoadModelType.
ep1
First term voltage exponent for active power (Ep1). Used only when .staticLoadModelType = exponential.
ep2
Second term voltage exponent for active power (Ep2). Used only when .staticLoadModelType = exponential.
ep3
Third term voltage exponent for active power (Ep3). Used only when .staticLoadModelType = exponential.
kpf
Frequency deviation coefficient for active power (Kpf). Not used when .staticLoadModelType = constantZ.
kq1
First term voltage coefficient for reactive power (Kq1). Not used when .staticLoadModelType = constantZ.
kq2
Second term voltage coefficient for reactive power (Kq2). Not used when .staticLoadModelType = constantZ.
kq3
Third term voltage coefficient for reactive power (Kq3). Not used when .staticLoadModelType = constantZ.
kq4
Frequency coefficient for reactive power (Kq4). Must be non-zero when .staticLoadModelType = ZIP2. Not used for all other values of .staticLoadModelType.
eq1
First term voltage exponent for reactive power (Eq1). Used only when .staticLoadModelType = exponential.
eq2
Second term voltage exponent for reactive power (Eq2). Used only when .staticLoadModelType = exponential.
eq3
Third term voltage exponent for reactive power (Eq3). Used only when .staticLoadModelType = exponential.
kqf
Frequency deviation coefficient for reactive power (Kqf). Not used when .staticLoadModelType = constantZ.
LoadMotor
Aggregate induction motor load. This model is used to represent a fraction of an ordinary load as "induction motor load". It allows load that is treated as ordinary constant power in power flow analysis to be represented by an induction motor in dynamic simulation. If Lpp = 0. or Lpp = Lp, or Tppo = 0., only one cage is represented. Magnetic saturation is not modelled. Either a "one-cage" or "two-cage" model of the induction machine can be modelled. Magnetic saturation is not modelled.
This model is intended for representation of aggregations of many motors dispersed through a load represented at a high voltage bus but where there is no information on the characteristics of individual motors.
This model treats a fraction of the constant power part of a load as a motor. During initialisation, the initial power drawn by the motor is set equal to Pfrac times the constant P part of the static load. The remainder of the load is left as static load.
The reactive power demand of the motor is calculated during initialisation as a function of voltage at the load bus. This reactive power demand may be less than or greater than the constant Q component of the load. If the motor's reactive demand is greater than the constant Q component of the load, the model inserts a shunt capacitor at the terminal of the motor to bring its reactive demand down to equal the constant Q reactive load.
If a motor model and a static load model are both present for a load, the motor Pfrac is assumed to be subtracted from the power flow constant P load before the static load model is applied. The remainder of the load, if any, is then represented by the static load model.
pfrac
Fraction of constant-power load to be represented by this motor model (Pfrac) (>=0.0 and <=1.0). Typical Value = 0.3.
lfac
Loading factor – ratio of initial P to motor MVA base (Lfac). Typical Value = 0.8.
ls
Synchronous reactance (Ls). Typical Value = 3.2.
lp
Transient reactance (Lp). Typical Value = 0.15.
lpp
Subtransient reactance (Lpp). Typical Value = 0.15.
ra
Stator resistance (Ra). Typical Value = 0.
tpo
Transient rotor time constant (Tpo) (not=0). Typical Value = 1.
tppo
Subtransient rotor time constant (Tppo). Typical Value = 0.02.
h
Inertia constant (H) (not=0). Typical Value = 0.4.
d
Damping factor (D). Unit = delta P/delta speed. Typical Value = 2.
vt
Voltage threshold for tripping (Vt). Typical Value = 0.7.
tv
Voltage trip pickup time (Tv). Typical Value = 0.1.
tbkr
Circuit breaker operating time (Tbkr). Typical Value = 0.08.
PK ! tb b Y cimpyorm/res/schemata/CIM16/DynamicsProfileRDFSAugmented_noAbstract-v2_4_15-16Feb2016.rdf
DynamicsProfile
The CIM dynamic model definitions reflect the most common IEEE or, in the case of wind models, IEC, representations of models as well as models included in some of the transient stability software widely used by utilities.
These dynamic models are intended to ensure interoperability between different vendors’ software products currently in use by electric utility energy companies, utilities, TSOs and RTO/ISOs. It is important to note that each vendor is free to select its own internal implementation of these models. Differences in vendor results, as long as they are within accepted engineering practice, caused by different internal representations, are acceptable.
Notes:
1. Wind models package is defined in accordance with IEC 61400-27-1 version CDV 2013-08-15.
DynamicsVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURI
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/Dynamics/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
Core
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
abstract
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
abstract
ConductingEquipment
The conducting equipment of the terminal. Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
Yes
Terminals
Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
Terminals
No
Equipment
The parts of a power system that are physical devices, electronic or mechanical.
abstract
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
abstract
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
abstract
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
abstract
Terminal
Remote terminal with which this input signal is associated.
Yes
RemoteInputSignal
Input signal coming from this terminal.
RemoteInputSignal
No
Wires
AsynchronousMachine
A rotating machine whose shaft rotates asynchronously with the electrical field. Also known as an induction machine with no external connection to the rotor windings, e.g squirrel-cage induction machine.
abstract
AsynchronousMachine
Asynchronous machine to which this asynchronous machine dynamics model applies.
Yes
AsynchronousMachineDynamics
Asynchronous machine dynamics model used to describe dynamic behavior of this asynchronous machine.
AsynchronousMachineDynamics
No
EnergyConsumer
Generic user of energy - a point of consumption on the power system model.
abstract
Description
EnergyConsumer
Energy consumer to which this dynamics load model applies.
No
LoadDynamics
Load dynamics model used to describe dynamic behavior of this energy consumer.
LoadDynamics
Yes
EnergySource
A generic equivalent for an energy supplier on a transmission or distribution voltage level.
abstract
EnergySource
Energy Source (current source) with which this wind Type 3 or 4 dynamics model is asoociated.
Yes
WindTurbineType3or4Dynamics
Wind generator Type 3 or 4 dynamics model associated with this energy source.
WindTurbineType3or4Dynamics
No
RegulatingCondEq
A type of conducting equipment that can regulate a quantity (i.e. voltage or flow) at a specific point in the network.
abstract
RotatingMachine
A rotating machine which may be used as a generator or motor.
abstract
SynchronousMachine
An electromechanical device that operates with shaft rotating synchronously with the network. It is a single machine operating either as a generator or synchronous condenser or pump.
abstract
SynchronousMachine
Synchronous machine to which synchronous machine dynamics model applies.
Yes
SynchronousMachineDynamics
Synchronous machine dynamics model used to describe dynamic behavior of this synchronous machine.
SynchronousMachineDynamics
No
StandardInterconnections
This section describes the standard interconnections for various types of equipment. These interconnections are understood by the application programs and can be identified based on the presence of one of the key classes with a relationship to the static power flow model: SynchronousMachineDynamics, AsynchronousMachineDynamics, EnergyConsumerDynamics or WindTurbineType3or4Dynamics.
The relationships between classes expressed in the interconnection diagrams are intended to support dynamic behaviour described by either standard models or user-defined models.
In the interconnection diagrams, boxes which are black in colour represent function blocks whose functionality can be provided by one of many standard models or by a used-defined model. Blue boxes represent specific standard models. A dashed box means that the function block or specific standard model is optional.
RemoteInputSignal
Supports connection to a terminal associated with a remote bus from which an input signal of a specific type is coming.
remoteSignalType
Type of input signal.
RemoteSignalKind
Type of input signal coming from remote bus.
remoteBusVoltageFrequency
Input is voltage frequency from remote terminal bus.
remoteBusVoltageFrequencyDeviation
Input is voltage frequency deviation from remote terminal bus.
remoteBusFrequency
Input is frequency from remote terminal bus.
remoteBusFrequencyDeviation
Input is frequency deviation from remote terminal bus.
remoteBusVoltageAmplitude
Input is voltage amplitude from remote terminal bus.
remoteBusVoltage
Input is voltage from remote terminal bus.
remoteBranchCurrentAmplitude
Input is branch current amplitude from remote terminal bus.
remoteBusVoltageAmplitudeDerivative
Input is branch current amplitude derivative from remote terminal bus.
remotePuBusVoltageDerivative
Input is PU voltage derivative from remote terminal bus.
RemoteInputSignal
Remote input signal used by this Power Factor or VAr controller Type I model.
No
PFVArControllerType1Dynamics
Power Factor or VAr controller Type I model using this remote input signal.
PFVArControllerType1Dynamics
Yes
RemoteInputSignal
Remote input signal used by this underexcitation limiter model.
No
UnderexcitationLimiterDynamics
Underexcitation limiter model using this remote input signal.
UnderexcitationLimiterDynamics
Yes
RemoteInputSignal
Remote input signal used by this wind generator Type 1 or Type 2 model.
Yes
WindTurbineType1or2Dynamics
Wind generator Type 1 or Type 2 model using this remote input signal.
WindTurbineType1or2Dynamics
No
RemoteInputSignal
Remote input signal used by this voltage compensator model.
No
VoltageCompensatorDynamics
Voltage compensator model using this remote input signal.
VoltageCompensatorDynamics
Yes
RemoteInputSignal
Remote input signal used by this power system stabilizer model.
No
PowerSystemStabilizerDynamics
Power system stabilizer model using this remote input signal.
PowerSystemStabilizerDynamics
Yes
RemoteInputSignal
Remote input signal used by this discontinuous excitation control system model.
No
DiscontinuousExcitationControlDynamics
Discontinuous excitation control model using this remote input signal.
DiscontinuousExcitationControlDynamics
Yes
WindTurbineType3or4Dynamics
Remote input signal used by these wind turbine Type 3 or 4 models.
No
RemoteInputSignal
Wind turbine Type 3 or 4 models using this remote input signal.
RemoteInputSignal
Yes
WindPlantDynamics
The remote signal with which this power plant is associated.
No
RemoteInputSignal
The wind plant using the remote signal.
RemoteInputSignal
Yes
StandardModels
This section contains standard dynamic model specifications grouped into packages by standard function block (type of equipment being modelled).
In the CIM, standard dynamic models are expressed by means of a class named with the standard model name and attributes reflecting each of the parameters necessary to describe the behaviour of an instance of the standard model.
DynamicsFunctionBlock
Abstract parent class for all Dynamics function blocks.
abstract
enabled
Function block used indicator.
true = use of function block is enabled
false = use of function block is disabled.
Boolean
A type with the value space "true" and "false".
Primitive
RotatingMachineDynamics
Abstract parent class for all synchronous and asynchronous machine standard models.
abstract
damping
Damping torque coefficient (D). A proportionality constant that, when multiplied by the angular velocity of the rotor poles with respect to the magnetic field (frequency), results in the damping torque. This value is often zero when the sources of damping torques (generator damper windings, load damping effects, etc.) are modelled in detail. Typical Value = 0.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
inertia
Inertia constant of generator or motor and mechanical load (H) (>0). This is the specification for the stored energy in the rotating mass when operating at rated speed. For a generator, this includes the generator plus all other elements (turbine, exciter) on the same shaft and has units of MW*sec. For a motor, it includes the motor plus its mechanical load. Conventional units are per unit on the generator MVA base, usually expressed as MW*second/MVA or just second. This value is used in the accelerating power reference frame for operator training simulator solutions. Typical Value = 3.
Seconds
Time, in seconds.
CIMDatatype
value
Time, in seconds
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
saturationFactor
Saturation factor at rated terminal voltage (S1) (> or =0). Not used by simplified model. Defined by defined by S(E1) in the SynchronousMachineSaturationParameters diagram. Typical Value = 0.02.
saturationFactor120
Saturation factor at 120% of rated terminal voltage (S12) (> or =S1). Not used by the simplified model, defined by S(E2) in the SynchronousMachineSaturationParameters diagram. Typical Value = 0.12.
statorLeakageReactance
Stator leakage reactance (Xl) (> or =0). Typical Value = 0.15.
PU
Per Unit - a positive or negative value referred to a defined base. Values typically range from -10 to +10.
CIMDatatype
value
unit
multiplier
statorResistance
Stator (armature) resistance (Rs) (> or =0). Typical Value = 0.005.
UserDefinedModels
This package contains user-defined dynamic model classes to support the exchange of both proprietary and explicitly defined models.
Proprietary models have behavior which, while not defined by a standard model class, is mutually understood by the sending and receiving applications based on the name passed in the .name attribute of the xxxUserDefined class. Parameters are passed as general attributes using as many instances of the ProprietaryParameterDynamics class as there are parameters.
Explicitly defined models describe dynamic behavior in detail in terms of control blocks and their input and output signals. NOTE: The classes to support explicitly defined modeling are not currently defined - it is future work. They are described here to document the current thinking on where they would be added.
WindPlantUserDefined
Wind plant function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
No
WindPlantUserDefined
Proprietary user-defined model with which this parameter is associated.
WindPlantUserDefined
Yes
WindType1or2UserDefined
Wind Type 1 or Type 2 function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
No
WindType1or2UserDefined
Proprietary user-defined model with which this parameter is associated.
WindType1or2UserDefined
Yes
WindType3or4UserDefined
Wind Type 3 or Type 4 function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
No
WindType3or4UserDefined
Proprietary user-defined model with which this parameter is associated.
WindType3or4UserDefined
Yes
SynchronousMachineUserDefined
Synchronous machine whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
SynchronousMachineUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
AsynchronousMachineUserDefined
Asynchronous machine whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
AsynchronousMachineUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
TurbineGovernorUserDefined
Turbine-governor function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
TurbineGovernorUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
TurbineLoadControllerUserDefined
Turbine load controller function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
TurbineLoadControllerUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
MechanicalLoadUserDefined
Mechanical load function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
MechanicalLoadUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
ExcitationSystemUserDefined
Excitation system function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
ExcitationSystemUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
OverexcitationLimiterUserDefined
Overexcitation limiter system function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
OverexcitationLimiterUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
UnderexcitationLimiterUserDefined
Underexcitation limiter function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
UnderexcitationLimiterUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
PowerSystemStabilizerUserDefined
Power system stabilizer function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
PowerSystemStabilizerUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
DiscontinuousExcitationControlUserDefined
Discontinuous excitation control function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
DiscontinuousExcitationControlUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
PFVArControllerType1UserDefined
Power Factor or VAr controller Type I function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
PFVArControllerType1UserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
VoltageAdjusterUserDefined
Voltage adjuster function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
VoltageAdjusterUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
PFVArControllerType2UserDefined
Power Factor or VAr controller Type II function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
PFVArControllerType2UserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
VoltageCompensatorUserDefined
Voltage compensator function block whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
VoltageCompensatorUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
LoadUserDefined
Load whose dynamic behaviour is described by a user-defined model.
proprietary
Behaviour is based on proprietary model as opposed to detailed model.
true = user-defined model is proprietary with behaviour mutually understood by sending and receiving applications and parameters passed as general attributes
false = user-defined model is explicitly defined in terms of control blocks and their input and output signals.
LoadUserDefined
Proprietary user-defined model with which this parameter is associated.
Yes
ProprietaryParameterDynamics
Parameter of this proprietary user-defined model.
ProprietaryParameterDynamics
No
ProprietaryParameterDynamics
Supports definition of one or more parameters of several different datatypes for use by proprietary user-defined models. NOTE: This class does not inherit from IdentifiedObject since it is not intended that a single instance of it be referenced by more than one proprietary user-defined model instance.
parameterNumber
Sequence number of the parameter among the set of parameters associated with the related proprietary user-defined model.
Integer
An integer number. The range is unspecified and not limited.
Primitive
booleanParameterValue
Used for boolean parameter value. If this attribute is populated, integerParameterValue and floatParameterValue will not be.
integerParameterValue
Used for integer parameter value. If this attribute is populated, booleanParameterValue and floatParameterValue will not be.
floatParameterValue
Used for floating point parameter value. If this attribute is populated, booleanParameterValue and integerParameterValue will not be.
SynchronousMachineDynamics
For conventional power generating units (e.g., thermal, hydro, combustion turbine), a synchronous machine model represents the electrical characteristics of the generator and the mechanical characteristics of the turbine-generator rotational inertia. Large industrial motors or groups of similar motors may be represented by individual motor models which are represented as generators with negative active power in the static (power flow) data.
The interconnection with the electrical network equations may differ among simulation tools. The tool only needs to know the synchronous machine to establish the correct interconnection. The interconnection with motor’s equipment could also differ due to input and output signals required by standard models.
SynchronousMachineSimplified
The simplified model represents a synchronous generator as a constant internal voltage behind an impedance (Rs + jXp) as shown in the Simplified diagram.
Since internal voltage is held constant, there is no Efd input and any excitation system model will be ignored. There is also no Ifd output.
This model should not be used for representing a real generator except, perhaps, small generators whose response is insignificant.
The parameters used for the Simplified model include:
- RotatingMachineDynamics.damping (D)
- RotatingMachineDynamics.inertia (H)
- RotatingMachineDynamics.statorLeakageReactance (used to exchange jXp for SynchronousMachineSimplified)
- RotatingMachineDynamics.statorResistance (Rs).
SynchronousMachineDynamics
Synchronous machine whose behaviour is described by reference to a standard model expressed in one of the following forms:
- simplified (or classical), where a group of generators or motors is not modelled in detail
- detailed, in equivalent circuit form
- detailed, in time constant reactance form
or by definition of a user-defined model.
Note: It is a common practice to represent small generators by a negative load rather than by a dynamic generator model when performing dynamics simulations. In this case a SynchronousMachine in the static model is not represented by anything in the dynamics model, instead it is treated as ordinary load.
Parameter Notes:
- Synchronous machine parameters such as Xl, Xd, Xp etc. are actually used as inductances (L) in the models, but are commonly referred to as reactances since, at nominal frequency, the per unit values are the same. However, some references use the symbol L instead of X.
abstract
SynchronousMachineDynamics
Turbine-governor model associated with this synchronous machine model.
Yes
TurbineGovernorDynamics
Synchronous machine model with which this turbine-governor model is associated.
TurbineGovernorDynamics
No
SynchronousMachineDynamics
Synchronous machine model with which this excitation system model is associated.
Yes
ExcitationSystemDynamics
Excitation system model associated with this synchronous machine model.
ExcitationSystemDynamics
No
SynchronousMachineDynamics
Synchronous machine model with which this mechanical load model is associated.
Yes
MechanicalLoadDynamics
Mechanical load model associated with this synchronous machine model.
MechanicalLoadDynamics
No
SynchronousMachineDynamics
Standard synchronous machine out of which current flow is being compensated for.
Yes
GenICompensationForGenJ
Compensation of voltage compensator's generator for current flow out of this generator.
GenICompensationForGenJ
No
SynchronousMachineDetailed
All synchronous machine detailed types use a subset of the same data parameters and input/output variables.
The several variations differ in the following ways:
- The number of equivalent windings that are included
- The way in which saturation is incorporated into the model.
- Whether or not “subtransient saliency” (X''q not = X''d) is represented.
Note: It is not necessary for each simulation tool to have separate models for each of the model types. The same model can often be used for several types by alternative logic within the model. Also, differences in saturation representation may not result in significant model performance differences so model substitutions are often acceptable.
abstract
saturationFactorQAxis
Q-axis saturation factor at rated terminal voltage (S1q) (>= 0). Typical Value = 0.02.
saturationFactor120QAxis
Q-axis saturation factor at 120% of rated terminal voltage (S12q) (>=S1q). Typical Value = 0.12.
efdBaseRatio
Ratio of Efd bases of exciter and generator models. Typical Value = 1.
ifdBaseType
Excitation base system mode. Typical Value = ifag.
IfdBaseKind
Excitation base system mode.
ifag
Air gap line mode. ifdBaseValue is computed, not defined by the user, in this mode.
ifnl
No load system with saturation mode. ifdBaseValue is computed, not defined by the user, in this mode.
iffl
Full load system mode. ifdBaseValue is computed, not defined by the user, in this mode.
other
Free mode. ifdBaseValue is defined by the user in this mode.
ifdBaseValue
Ifd base current if .ifdBaseType = other.
Not needed if .ifdBaseType not = other.
Unit = A. Typical Value = 0.
CurrentFlow
Electrical current with sign convention: positive flow is out of the conducting equipment into the connectivity node. Can be both AC and DC.
CIMDatatype
value
unit
multiplier
SynchronousMachineTimeConstantReactance
Synchronous machine detailed modelling types are defined by the combination of the attributes SynchronousMachineTimeConstantReactance.modelType and SynchronousMachineTimeConstantReactance.rotorType.
Parameter notes:
- The “p” in the time-related attribute names is a substitution for a “prime” in the usual parameter notation, e.g. tpdo refers to T'do.
The parameters used for models expressed in time constant reactance form include:
- RotatingMachine.ratedS (MVAbase)
- RotatingMachineDynamics.damping (D)
- RotatingMachineDynamics.inertia (H)
- RotatingMachineDynamics.saturationFactor (S1)
- RotatingMachineDynamics.saturationFactor120 (S12)
- RotatingMachineDynamics.statorLeakageReactance (Xl)
- RotatingMachineDynamics.statorResistance (Rs)
- SynchronousMachineTimeConstantReactance.ks (Ks)
- SynchronousMachineDetailed.saturationFactorQAxis (S1q)
- SynchronousMachineDetailed.saturationFactor120QAxis (S12q)
- SynchronousMachineDetailed.efdBaseRatio
- SynchronousMachineDetailed.ifdBaseType
- SynchronousMachineDetailed.ifdBaseValue, if present
- .xDirectSync (Xd)
- .xDirectTrans (X'd)
- .xDirectSubtrans (X''d)
- .xQuadSync (Xq)
- .xQuadTrans (X'q)
- .xQuadSubtrans (X''q)
- .tpdo (T'do)
- .tppdo (T''do)
- .tpqo (T'qo)
- .tppqo (T''qo)
- .tc.
rotorType
Type of rotor on physical machine.
RotorKind
Type of rotor on physical machine.
roundRotor
Round rotor type of synchronous machine.
salientPole
Salient pole type of synchronous machine.
modelType
Type of synchronous machine model used in Dynamic simulation applications.
SynchronousMachineModelKind
Type of synchronous machine model used in Dynamic simulation applications.
subtransient
Subtransient synchronous machine model.
subtransientTypeF
WECC Type F variant of subtransient synchronous machine model.
subtransientTypeJ
WECC Type J variant of subtransient synchronous machine model.
subtransientSimplified
Simplified version of subtransient synchronous machine model where magnetic coupling between the direct and quadrature axes is ignored.
subtransientSimplifiedDirectAxis
Simplified version of a subtransient synchronous machine model with no damper circuit on d-axis.
ks
Saturation loading correction factor (Ks) (>= 0). Used only by Type J model. Typical Value = 0.
xDirectSync
Direct-axis synchronous reactance (Xd) (>= X'd).
The quotient of a sustained value of that AC component of armature voltage that is produced by the total direct-axis flux due to direct-axis armature current and the value of the AC component of this current, the machine running at rated speed. Typical Value = 1.8.
xDirectTrans
Direct-axis transient reactance (unsaturated) (X'd) (> =X''d). Typical Value = 0.5.
xDirectSubtrans
Direct-axis subtransient reactance (unsaturated) (X''d) (> Xl). Typical Value = 0.2.
xQuadSync
Quadrature-axis synchronous reactance (Xq) (> =X'q).
The ratio of the component of reactive armature voltage, due to the quadrature-axis component of armature current, to this component of current, under steady state conditions and at rated frequency. Typical Value = 1.6.
xQuadTrans
Quadrature-axis transient reactance (X'q) (> =X''q). Typical Value = 0.3.
xQuadSubtrans
Quadrature-axis subtransient reactance (X''q) (> Xl). Typical Value = 0.2.
tpdo
Direct-axis transient rotor time constant (T'do) (> T''do). Typical Value = 5.
tppdo
Direct-axis subtransient rotor time constant (T''do) (> 0). Typical Value = 0.03.
tpqo
Quadrature-axis transient rotor time constant (T'qo) (> T''qo). Typical Value = 0.5.
tppqo
Quadrature-axis subtransient rotor time constant (T''qo) (> 0). Typical Value = 0.03.
tc
Damping time constant for “Canay” reactance. Typical Value = 0.
SynchronousMachineEquivalentCircuit
The electrical equations for all variations of the synchronous models are based on the SynchronousEquivalentCircuit diagram for the direct and quadrature axes.
Equations for conversion between Equivalent Circuit and Time Constant Reactance forms:
Xd = Xad + Xl
X’d = Xl + Xad * Xfd / (Xad + Xfd)
X”d = Xl + Xad * Xfd * X1d / (Xad * Xfd + Xad * X1d + Xfd * X1d)
Xq = Xaq + Xl
X’q = Xl + Xaq * X1q / (Xaq+ X1q)
X”q = Xl + Xaq * X1q* X2q / (Xaq * X1q + Xaq * X2q + X1q * X2q)
T’do = (Xad + Xfd) / (omega0 * Rfd)
T”do = (Xad * Xfd + Xad * X1d + Xfd * X1d) / (omega0 * R1d * (Xad + Xfd)
T’qo = (Xaq + X1q) / (omega0 * R1q)
T”qo = (Xaq * X1q + Xaq * X2q + X1q * X2q)/ (omega0 * R2q * (Xaq + X1q)
Same equations using CIM attributes from SynchronousMachineTimeConstantReactance class on left of = sign and SynchronousMachineEquivalentCircuit class on right (except as noted):
xDirectSync = xad + RotatingMachineDynamics.statorLeakageReactance
xDirectTrans = RotatingMachineDynamics.statorLeakageReactance + xad * xfd / (xad + xfd)
xDirectSubtrans = RotatingMachineDynamics.statorLeakageReactance + xad * xfd * x1d / (xad * xfd + xad * x1d + xfd * x1d)
xQuadSync = xaq + RotatingMachineDynamics.statorLeakageReactance
xQuadTrans = RotatingMachineDynamics.statorLeakageReactance + xaq * x1q / (xaq+ x1q)
xQuadSubtrans = RotatingMachineDynamics.statorLeakageReactance + xaq * x1q* x2q / (xaq * x1q + xaq * x2q + x1q * x2q)
tpdo = (xad + xfd) / (2*pi*nominal frequency * rfd)
tppdo = (xad * xfd + xad * x1d + xfd * x1d) / (2*pi*nominal frequency * r1d * (xad + xfd)
tpqo = (xaq + x1q) / (2*pi*nominal frequency * r1q)
tppqo = (xaq * x1q + xaq * x2q + x1q * x2q)/ (2*pi*nominal frequency * r2q * (xaq + x1q).
Are only valid for a simplified model where "Canay" reactance is zero.
xad
D-axis mutual reactance.
rfd
Field winding resistance.
xfd
Field winding leakage reactance.
r1d
D-axis damper 1 winding resistance.
x1d
D-axis damper 1 winding leakage reactance.
xf1d
Differential mutual (“Canay”) reactance.
xaq
Q-axis mutual reactance.
r1q
Q-axis damper 1 winding resistance.
x1q
Q-axis damper 1 winding leakage reactance.
r2q
Q-axis damper 2 winding resistance.
x2q
Q-axis damper 2 winding leakage reactance.
AsynchronousMachineDynamics
An asynchronous machine model represents a (induction) generator or motor with no external connection to the rotor windings, e.g., squirrel-cage induction machine.
The interconnection with the electrical network equations may differ among simulation tools. The program only needs to know the terminal to which this asynchronous machine is connected in order to establish the correct interconnection. The interconnection with motor’s equipment could also differ due to input and output signals required by standard models.
The asynchronous machine model is used to model wind generators Type 1 and Type 2. For these, normal practice is to include the rotor flux transients and neglect the stator flux transients.
AsynchronousMachineDynamics
Asynchronous machine whose behaviour is described by reference to a standard model expressed in either time constant reactance form or equivalent circuit form or by definition of a user-defined model.
Parameter Notes:
- Asynchronous machine parameters such as Xl, Xs etc. are actually used as inductances (L) in the model, but are commonly referred to as reactances since, at nominal frequency, the per unit values are the same. However, some references use the symbol L instead of X.
abstract
AsynchronousMachineDynamics
Asynchronous machine model with which this mechanical load model is associated.
Yes
MechanicalLoadDynamics
Mechanical load model associated with this asynchronous machine model.
MechanicalLoadDynamics
No
AsynchronousMachineDynamics
Asynchronous machine model with which this wind generator type 1 or 2 model is associated.
Yes
WindTurbineType1or2Dynamics
Wind generator type 1 or 2 model associated with this asynchronous machine model.
WindTurbineType1or2Dynamics
No
AsynchronousMachineDynamics
Asynchronous machine model with which this turbine-governor model is associated.
Yes
TurbineGovernorDynamics
Turbine-governor model associated with this asynchronous machine model.
TurbineGovernorDynamics
No
AsynchronousMachineTimeConstantReactance
Parameter Notes:
- If X'' = X', a single cage (one equivalent rotor winding per axis) is modelled.
- The “p” in the attribute names is a substitution for a “prime” in the usual parameter notation, e.g. tpo refers to T'o.
The parameters used for models expressed in time constant reactance form include:
- RotatingMachine.ratedS (MVAbase)
- RotatingMachineDynamics.damping (D)
- RotatingMachineDynamics.inertia (H)
- RotatingMachineDynamics.saturationFactor (S1)
- RotatingMachineDynamics.saturationFactor120 (S12)
- RotatingMachineDynamics.statorLeakageReactance (Xl)
- RotatingMachineDynamics.statorResistance (Rs)
- .xs (Xs)
- .xp (X')
- .xpp (X'')
- .tpo (T'o)
- .tppo (T''o).
xs
Synchronous reactance (Xs) (>= X'). Typical Value = 1.8.
xp
Transient reactance (unsaturated) (X') (>=X''). Typical Value = 0.5.
xpp
Subtransient reactance (unsaturated) (X'') (> Xl). Typical Value = 0.2.
tpo
Transient rotor time constant (T'o) (> T''o). Typical Value = 5.
tppo
Subtransient rotor time constant (T''o) (> 0). Typical Value = 0.03.
AsynchronousMachineEquivalentCircuit
The electrical equations of all variations of the asynchronous model are based on the AsynchronousEquivalentCircuit diagram for the direct and quadrature axes, with two equivalent rotor windings in each axis.
Equations for conversion between Equivalent Circuit and Time Constant Reactance forms:
Xs = Xm + Xl
X' = Xl + Xm * Xlr1 / (Xm + Xlr1)
X'' = Xl + Xm * Xlr1* Xlr2 / (Xm * Xlr1 + Xm * Xlr2 + Xlr1 * Xlr2)
T'o = (Xm + Xlr1) / (omega0 * Rr1)
T''o = (Xm * Xlr1 + Xm * Xlr2 + Xlr1 * Xlr2) / (omega0 * Rr2 * (Xm + Xlr1)
Same equations using CIM attributes from AsynchronousMachineTimeConstantReactance class on left of = sign and AsynchronousMachineEquivalentCircuit class on right (except as noted):
xs = xm + RotatingMachineDynamics.statorLeakageReactance
xp = RotatingMachineDynamics.statorLeakageReactance + xm * xlr1 / (xm + xlr1)
xpp = RotatingMachineDynamics.statorLeakageReactance + xm * xlr1* xlr2 / (xm * xlr1 + xm * xlr2 + xlr1 * xlr2)
tpo = (xm + xlr1) / (2*pi*nominal frequency * rr1)
tppo = (xm * xlr1 + xm * xlr2 + xlr1 * xlr2) / (2*pi*nominal frequency * rr2 * (xm + xlr1).
xm
Magnetizing reactance.
rr1
Damper 1 winding resistance.
xlr1
Damper 1 winding leakage reactance.
rr2
Damper 2 winding resistance.
xlr2
Damper 2 winding leakage reactance.
TurbineGovernorDynamics
The turbine-governor model is linked to one or two synchronous generators and determines the shaft mechanical power (Pm) or torque (Tm) for the generator model.
Unlike IEEE standard models for other function blocks, the three IEEE turbine-governor standard models (GovHydroIEEE0, GovHydroIEEE2, GovSteamIEEE1) are documented in IEEE Transactions not in IEEE standards. For that reason, diagrams are supplied for those models.
A 2012 IEEE report, Dynamic Models for Turbine-Governors in Power System Studies, provides updated information on a variety of models including IEEE, vendor and reliability authority models. Fully incorporating the results of that report into the CIM Dynamics model is a future effort.
TurbineGovernorDynamics
Turbine-governor function block whose behavior is described by reference to a standard model or by definition of a user-defined model.
abstract
TurbineGovernorDynamics
Turbine-governor controlled by this turbine load controller.
Yes
TurbineLoadControllerDynamics
Turbine load controller providing input to this turbine-governor.
TurbineLoadControllerDynamics
No
GovHydroIEEE0
IEEE Simplified Hydro Governor-Turbine Model. Used for Mechanical-Hydraulic and Electro-Hydraulic turbine governors, with our without steam feedback. Typical values given are for Mechanical-Hydraulic.
Reference: IEEE Transactions on Power Apparatus and Systems
November/December 1973, Volume PAS-92, Number 6
Dynamic Models for Steam and Hydro Turbines in Power System Studies, Page 1904.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
ActivePower
Product of RMS value of the voltage and the RMS value of the in-phase component of the current.
CIMDatatype
value
unit
multiplier
k
Governor gain (K).
t1
Governor lag time constant (T1). Typical Value = 0.25.
t2
Governor lead time constant (T2). Typical Value = 0.
t3
Gate actuator time constant (T3). Typical Value = 0.1.
t4
Water starting time (T4).
pmax
Gate maximum (Pmax).
pmin
Gate minimum (Pmin).
GovHydroIEEE2
IEEE hydro turbine governor model represents plants with straightforward penstock configurations and hydraulic-dashpot governors.
Reference: IEEE Transactions on Power Apparatus and Systems
November/December 1973, Volume PAS-92, Number 6
Dynamic Models for Steam and Hydro Turbines in Power System Studies, Page 1904.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
tg
Gate servo time constant (Tg). Typical Value = 0.5.
tp
Pilot servo valve time constant (Tp). Typical Value = 0.03.
uo
Maximum gate opening velocity (Uo). Unit = PU/sec. Typical Value = 0.1.
uc
Maximum gate closing velocity (Uc) (<0). Typical Value = -0.1.
pmax
Maximum gate opening (Pmax). Typical Value = 1.
pmin
Minimum gate opening (Pmin). Typical Value = 0.
rperm
Permanent droop (Rperm). Typical Value = 0.05.
rtemp
Temporary droop (Rtemp). Typical Value = 0.5.
tr
Dashpot time constant (Tr). Typical Value = 12.
tw
Water inertia time constant (Tw). Typical Value = 2.
kturb
Turbine gain (Kturb). Typical Value = 1.
aturb
Turbine numerator multiplier (Aturb). Typical Value = -1.
bturb
Turbine denominator multiplier (Bturb). Typical Value = 0.5.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovSteamIEEE1
IEEE steam turbine governor model.
Reference: IEEE Transactions on Power Apparatus and Systems
November/December 1973, Volume PAS-92, Number 6
Dynamic Models for Steam and Hydro Turbines in Power System Studies, Page 1904.
Parameter Notes:
- Per unit parameters are on base of MWbase, which is normally the MW capability of the turbine.
- T3 must be greater than zero. All other time constants may be zero.
- For a tandem-compound turbine the parameters K2, K4, K6, and K8 are ignored. For a cross-compound turbine, two generators are connected to this turbine-governor model.
- Each generator must be represented in the load flow by data on its own MVA base. The values of K1, K3, K5, K7 must be specified to describe the proportionate development of power on the first turbine shaft. K2, K4, K6, K8 must describe the second turbine shaft. Normally K1 + K3 + K5 + K7 = 1.0 and K2 + K4 + K6 + K8 = 1.0 (if second generator is present).
- The division of power between the two shafts is in proportion to the values of MVA bases of the two generators. The initial condition load flow should, therefore, have the two generators loaded to the same fraction of each one’s MVA base.
mwbase
Base for power values (MWbase) (> 0).
k
Governor gain (reciprocal of droop) (K) (> 0). Typical Value = 25.
t1
Governor lag time constant (T1). Typical Value = 0.
t2
Governor lead time constant (T2). Typical Value = 0.
t3
Valve positioner time constant (T3) (> 0). Typical Value = 0.1.
uo
Maximum valve opening velocity (Uo) (> 0). Unit = PU/sec. Typical Value = 1.
uc
Maximum valve closing velocity (Uc) (< 0). Unit = PU/sec. Typical Value = -10.
pmax
Maximum valve opening (Pmax) (> Pmin). Typical Value = 1.
pmin
Minimum valve opening (Pmin) (>= 0). Typical Value = 0.
t4
Inlet piping/steam bowl time constant (T4). Typical Value = 0.3.
k1
Fraction of HP shaft power after first boiler pass (K1). Typical Value = 0.2.
k2
Fraction of LP shaft power after first boiler pass (K2). Typical Value = 0.
t5
Time constant of second boiler pass (T5). Typical Value = 5.
k3
Fraction of HP shaft power after second boiler pass (K3). Typical Value = 0.3.
k4
Fraction of LP shaft power after second boiler pass (K4). Typical Value = 0.
t6
Time constant of third boiler pass (T6). Typical Value = 0.5.
k5
Fraction of HP shaft power after third boiler pass (K5). Typical Value = 0.5.
k6
Fraction of LP shaft power after third boiler pass (K6). Typical Value = 0.
t7
Time constant of fourth boiler pass (T7). Typical Value = 0.
k7
Fraction of HP shaft power after fourth boiler pass (K7). Typical Value = 0.
k8
Fraction of LP shaft power after fourth boiler pass (K8). Typical Value = 0.
GovCT1
General model for any prime mover with a PID governor, used primarily for combustion turbine and combined cycle units.
This model can be used to represent a variety of prime movers controlled by PID governors. It is suitable, for example, for representation of
- gas turbine and single shaft combined cycle turbines
- diesel engines with modern electronic or digital governors
- steam turbines where steam is supplied from a large boiler drum or a large header whose pressure is substantially constant over the period under study
- simple hydro turbines in dam configurations where the water column length is short and water inertia effects are minimal.
Additional information on this model is available in the 2012 IEEE report, Dynamic Models for Turbine-Governors in Power System Studies, section 3.1.2.3 page 3-4 (GGOV1).
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
r
Permanent droop (R). Typical Value = 0.04.
rselect
Feedback signal for droop (Rselect). Typical Value = electricalPower.
DroopSignalFeedbackKind
Governor droop signal feedback source.
electricalPower
Electrical power feedback (connection indicated as 1 in the block diagrams of models, e.g. GovCT1, GovCT2).
none
No droop signal feedback, is isochronous governor.
fuelValveStroke
Fuel valve stroke feedback (true stroke) (connection indicated as 2 in the block diagrams of model, e.g. GovCT1, GovCT2).
governorOutput
Governor output feedback (requested stroke) (connection indicated as 3 in the block diagrams of models, e.g. GovCT1, GovCT2).
tpelec
Electrical power transducer time constant (Tpelec) (>0). Typical Value = 1.
maxerr
Maximum value for speed error signal (maxerr). Typical Value = 0.05.
minerr
Minimum value for speed error signal (minerr). Typical Value = -0.05.
kpgov
Governor proportional gain (Kpgov). Typical Value = 10.
kigov
Governor integral gain (Kigov). Typical Value = 2.
kdgov
Governor derivative gain (Kdgov). Typical Value = 0.
tdgov
Governor derivative controller time constant (Tdgov). Typical Value = 1.
vmax
Maximum valve position limit (Vmax). Typical Value = 1.
vmin
Minimum valve position limit (Vmin). Typical Value = 0.15.
tact
Actuator time constant (Tact). Typical Value = 0.5.
kturb
Turbine gain (Kturb) (>0). Typical Value = 1.5.
wfnl
No load fuel flow (Wfnl). Typical Value = 0.2.
tb
Turbine lag time constant (Tb) (>0). Typical Value = 0.5.
tc
Turbine lead time constant (Tc). Typical Value = 0.
wfspd
Switch for fuel source characteristic to recognize that fuel flow, for a given fuel valve stroke, can be proportional to engine speed (Wfspd).
true = fuel flow proportional to speed (for some gas turbines and diesel engines with positive displacement fuel injectors)
false = fuel control system keeps fuel flow independent of engine speed.
Typical Value = true.
teng
Transport time delay for diesel engine used in representing diesel engines where there is a small but measurable transport delay between a change in fuel flow setting and the development of torque (Teng). Teng should be zero in all but special cases where this transport delay is of particular concern. Typical Value = 0.
tfload
Load Limiter time constant (Tfload) (>0). Typical Value = 3.
kpload
Load limiter proportional gain for PI controller (Kpload). Typical Value = 2.
kiload
Load limiter integral gain for PI controller (Kiload). Typical Value = 0.67.
ldref
Load limiter reference value (Ldref). Typical Value = 1.
dm
Speed sensitivity coefficient (Dm). Dm can represent either the variation of the engine power with the shaft speed or the variation of maximum power capability with shaft speed. If it is positive it describes the falling slope of the engine speed verses power characteristic as speed increases. A slightly falling characteristic is typical for reciprocating engines and some aero-derivative turbines. If it is negative the engine power is assumed to be unaffected by the shaft speed, but the maximum permissible fuel flow is taken to fall with falling shaft speed. This is characteristic of single-shaft industrial turbines due to exhaust temperature limits. Typical Value = 0.
ropen
Maximum valve opening rate (Ropen). Unit = PU/sec. Typical Value = 0.10.
rclose
Minimum valve closing rate (Rclose). Unit = PU/sec. Typical Value = -0.1.
kimw
Power controller (reset) gain (Kimw). The default value of 0.01 corresponds to a reset time of 100 seconds. A value of 0.001 corresponds to a relatively slow acting load controller. Typical Value = 0.01.
aset
Acceleration limiter setpoint (Aset). Unit = PU/sec. Typical Value = 0.01.
ka
Acceleration limiter gain (Ka). Typical Value = 10.
ta
Acceleration limiter time constant (Ta) (>0). Typical Value = 0.1.
db
Speed governor dead band in per unit speed (db). In the majority of applications, it is recommended that this value be set to zero. Typical Value = 0.
tsa
Temperature detection lead time constant (Tsa). Typical Value = 4.
tsb
Temperature detection lag time constant (Tsb). Typical Value = 5.
rup
Maximum rate of load limit increase (Rup). Typical Value = 99.
rdown
Maximum rate of load limit decrease (Rdown). Typical Value = -99.
GovCT2
General governor model with frequency-dependent fuel flow limit. This model is a modification of the GovCT1 model in order to represent the frequency-dependent fuel flow limit of a specific gas turbine manufacturer.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
r
Permanent droop (R). Typical Value = 0.05.
rselect
Feedback signal for droop (Rselect). Typical Value = electricalPower.
tpelec
Electrical power transducer time constant (Tpelec). Typical Value = 2.5.
maxerr
Maximum value for speed error signal (Maxerr). Typical Value = 1.
minerr
Minimum value for speed error signal (Minerr). Typical Value = -1.
kpgov
Governor proportional gain (Kpgov). Typical Value = 4.
kigov
Governor integral gain (Kigov). Typical Value = 0.45.
kdgov
Governor derivative gain (Kdgov). Typical Value = 0.
tdgov
Governor derivative controller time constant (Tdgov). Typical Value = 1.
vmax
Maximum valve position limit (Vmax). Typical Value = 1.
vmin
Minimum valve position limit (Vmin). Typical Value = 0.175.
tact
Actuator time constant (Tact). Typical Value = 0.4.
kturb
Turbine gain (Kturb). Typical Value = 1.9168.
wfnl
No load fuel flow (Wfnl). Typical Value = 0.187.
tb
Turbine lag time constant (Tb). Typical Value = 0.1.
tc
Turbine lead time constant (Tc). Typical Value = 0.
wfspd
Switch for fuel source characteristic to recognize that fuel flow, for a given fuel valve stroke, can be proportional to engine speed (Wfspd).
true = fuel flow proportional to speed (for some gas turbines and diesel engines with positive displacement fuel injectors)
false = fuel control system keeps fuel flow independent of engine speed.
Typical Value = false.
teng
Transport time delay for diesel engine used in representing diesel engines where there is a small but measurable transport delay between a change in fuel flow setting and the development of torque (Teng). Teng should be zero in all but special cases where this transport delay is of particular concern. Typical Value = 0.
tfload
Load Limiter time constant (Tfload). Typical Value = 3.
kpload
Load limiter proportional gain for PI controller (Kpload). Typical Value = 1.
kiload
Load limiter integral gain for PI controller (Kiload). Typical Value = 1.
ldref
Load limiter reference value (Ldref). Typical Value = 1.
dm
Speed sensitivity coefficient (Dm). Dm can represent either the variation of the engine power with the shaft speed or the variation of maximum power capability with shaft speed. If it is positive it describes the falling slope of the engine speed verses power characteristic as speed increases. A slightly falling characteristic is typical for reciprocating engines and some aero-derivative turbines. If it is negative the engine power is assumed to be unaffected by the shaft speed, but the maximum permissible fuel flow is taken to fall with falling shaft speed. This is characteristic of single-shaft industrial turbines due to exhaust temperature limits. Typical Value = 0.
ropen
Maximum valve opening rate (Ropen). Unit = PU/sec. Typical Value = 99.
rclose
Minimum valve closing rate (Rclose). Unit = PU/sec. Typical Value = -99.
kimw
Power controller (reset) gain (Kimw). The default value of 0.01 corresponds to a reset time of 100 seconds. A value of 0.001 corresponds to a relatively slow acting load controller. Typical Value = 0.
aset
Acceleration limiter setpoint (Aset). Unit = PU/sec. Typical Value = 10.
ka
Acceleration limiter Gain (Ka). Typical Value = 10.
ta
Acceleration limiter time constant (Ta). Typical Value = 1.
db
Speed governor dead band in per unit speed (db). In the majority of applications, it is recommended that this value be set to zero. Typical Value = 0.
tsa
Temperature detection lead time constant (Tsa). Typical Value = 0.
tsb
Temperature detection lag time constant (Tsb). Typical Value = 50.
rup
Maximum rate of load limit increase (Rup). Typical Value = 99.
rdown
Maximum rate of load limit decrease (Rdown). Typical Value = -99.
prate
Ramp rate for frequency-dependent power limit (Prate). Typical Value = 0.017.
flim1
Frequency threshold 1 (Flim1). Unit = Hz. Typical Value = 59.
Frequency
Cycles per second.
CIMDatatype
value
unit
multiplier
plim1
Power limit 1 (Plim1). Typical Value = 0.8325.
flim2
Frequency threshold 2 (Flim2). Unit = Hz. Typical Value = 0.
plim2
Power limit 2 (Plim2). Typical Value = 0.
flim3
Frequency threshold 3 (Flim3). Unit = Hz. Typical Value = 0.
plim3
Power limit 3 (Plim3). Typical Value = 0.
flim4
Frequency threshold 4 (Flim4). Unit = Hz. Typical Value = 0.
plim4
Power limit 4 (Plim4). Typical Value = 0.
flim5
Frequency threshold 5 (Flim5). Unit = Hz. Typical Value = 0.
plim5
Power limit 5 (Plim5). Typical Value = 0.
flim6
Frequency threshold 6 (Flim6). Unit = Hz. Typical Value = 0.
plim6
Power limit 6 (Plim6). Typical Value = 0.
flim7
Frequency threshold 7 (Flim7). Unit = Hz. Typical Value = 0.
plim7
Power limit 7 (Plim7). Typical Value = 0.
flim8
Frequency threshold 8 (Flim8). Unit = Hz. Typical Value = 0.
plim8
Power limit 8 (Plim8). Typical Value = 0.
flim9
Frequency threshold 9 (Flim9). Unit = Hz. Typical Value = 0.
plim9
Power Limit 9 (Plim9). Typical Value = 0.
flim10
Frequency threshold 10 (Flim10). Unit = Hz. Typical Value = 0.
plim10
Power limit 10 (Plim10). Typical Value = 0.
GovGAST
Single shaft gas turbine.
mwbase
Base for power values (MWbase) (> 0).
r
Permanent droop (R). Typical Value = 0.04.
t1
Governor mechanism time constant (T1). T1 represents the natural valve positioning time constant of the governor for small disturbances, as seen when rate limiting is not in effect. Typical Value = 0.5.
t2
Turbine power time constant (T2). T2 represents delay due to internal energy storage of the gas turbine engine. T2 can be used to give a rough approximation to the delay associated with acceleration of the compressor spool of a multi-shaft engine, or with the compressibility of gas in the plenum of a the free power turbine of an aero-derivative unit, for example. Typical Value = 0.5.
t3
Turbine exhaust temperature time constant (T3). Typical Value = 3.
at
Ambient temperature load limit (Load Limit). Typical Value = 1.
kt
Temperature limiter gain (Kt). Typical Value = 3.
vmax
Maximum turbine power, PU of MWbase (Vmax). Typical Value = 1.
vmin
Minimum turbine power, PU of MWbase (Vmin). Typical Value = 0.
dturb
Turbine damping factor (Dturb). Typical Value = 0.18.
GovGAST1
Modified single shaft gas turbine.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
r
Permanent droop (R). Typical Value = 0.04.
t1
Governor mechanism time constant (T1). T1 represents the natural valve positioning time constant of the governor for small disturbances, as seen when rate limiting is not in effect. Typical Value = 0.5.
t2
Turbine power time constant (T2). T2 represents delay due to internal energy storage of the gas turbine engine. T2 can be used to give a rough approximation to the delay associated with acceleration of the compressor spool of a multi-shaft engine, or with the compressibility of gas in the plenum of the free power turbine of an aero-derivative unit, for example. Typical Value = 0.5.
t3
Turbine exhaust temperature time constant (T3). T3 represents delay in the exhaust temperature and load limiting system. Typical Value = 3.
lmax
Ambient temperature load limit (Lmax). Lmax is the turbine power output corresponding to the limiting exhaust gas temperature. Typical Value = 1.
kt
Temperature limiter gain (Kt). Typical Value = 3.
vmax
Maximum turbine power, PU of MWbase (Vmax). Typical Value = 1.
vmin
Minimum turbine power, PU of MWbase (Vmin). Typical Value = 0.
fidle
Fuel flow at zero power output (Fidle). Typical Value = 0.18.
rmax
Maximum fuel valve opening rate (Rmax). Unit = PU/sec. Typical Value = 1.
loadinc
Valve position change allowed at fast rate (Loadinc). Typical Value = 0.05.
tltr
Valve position averaging time constant (Tltr). Typical Value = 10.
ltrate
Maximum long term fuel valve opening rate (Ltrate). Typical Value = 0.02.
a
Turbine power time constant numerator scale factor (a). Typical Value = 0.8.
b
Turbine power time constant denominator scale factor (b). Typical Value = 1.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2,PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
ka
Governor gain (Ka). Typical Value = 0.
t4
Governor lead time constant (T4). Typical Value = 0.
t5
Governor lag time constant (T5). Typical Value = 0.
GovGAST2
Gas turbine model.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
w
Governor gain (1/droop) on turbine rating (W).
x
Governor lead time constant (X).
y
Governor lag time constant (Y) (>0).
z
Governor mode (Z).
true = Droop
false = ISO.
etd
Turbine and exhaust delay (Etd).
tcd
Compressor discharge time constant (Tcd).
trate
Turbine rating (Trate). Unit = MW.
t
Fuel Control Time Constant (T).
tmax
Maximum Turbine limit (Tmax).
tmin
Minimum Turbine limit (Tmin).
ecr
Combustion reaction time delay (Ecr).
k3
Ratio of Fuel Adjustment (K3).
a
Valve positioner (A).
b
Valve positioner (B).
c
Valve positioner (C).
tf
Fuel system time constant (Tf).
kf
Fuel system feedback (Kf).
k5
Gain of radiation shield (K5).
k4
Gain of radiation shield (K4).
t3
Radiation shield time constant (T3).
t4
Thermocouple time constant (T4).
tt
Temperature controller integration rate (Tt).
t5
Temperature control time constant (T5).
af1
Exhaust temperature Parameter (Af1). Unit = per unit temperature. Based on temperature in degrees C.
bf1
(Bf1). Bf1 = E(1-w) where E (speed sensitivity coefficient) is 0.55 to 0.65 x Tr. Unit = per unit temperature. Based on temperature in degrees C.
af2
Coefficient equal to 0.5(1-speed) (Af2).
bf2
Turbine Torque Coefficient Khhv (depends on heating value of fuel stream in combustion chamber) (Bf2).
cf2
Coefficient defining fuel flow where power output is 0% (Cf2). Synchronous but no output. Typically 0.23 x Khhv (23% fuel flow).
tr
Rated temperature (Tr). Unit = °C depending on parameters Af1 and Bf1.
Temperature
Value of temperature in degrees Celsius.
CIMDatatype
multiplier
unit
value
k6
Minimum fuel flow (K6).
tc
Temperature control (Tc). Unit = °F or °C depending on constants Af1 and Bf1.
GovGAST3
Generic turbogas with acceleration and temperature controller.
bp
Droop (bp). Typical Value = 0.05.
tg
Time constant of speed governor (Tg). Typical Value = 0.05.
rcmx
Maximum fuel flow (RCMX). Typical Value = 1.
rcmn
Minimum fuel flow (RCMN). Typical Value = -0.1.
ky
Coefficient of transfer function of fuel valve positioner (Ky). Typical Value = 1.
ty
Time constant of fuel valve positioner (Ty). Typical Value = 0.2.
tac
Fuel control time constant (Tac). Typical Value = 0.1.
kac
Fuel system feedback (KAC). Typical Value = 0.
tc
Compressor discharge volume time constant (Tc). Typical Value = 0.2.
bca
Acceleration limit set-point (Bca). Unit = 1/s. Typical Value = 0.01.
kca
Acceleration control integral gain (Kca). Unit = 1/s. Typical Value = 100.
dtc
Exhaust temperature variation due to fuel flow increasing from 0 to 1 PU (deltaTc). Typical Value = 390.
ka
Minimum fuel flow (Ka). Typical Value = 0.23.
tsi
Time constant of radiation shield (Tsi). Typical Value = 15.
ksi
Gain of radiation shield (Ksi). Typical Value = 0.8.
ttc
Time constant of thermocouple (Ttc). Typical Value = 2.5.
tfen
Turbine rated exhaust temperature correspondent to Pm=1 PU (Tfen). Typical Value = 540.
td
Temperature controller derivative gain (Td). Typical Value = 3.3.
tt
Temperature controller integration rate (Tt). Typical Value = 250.
mxef
Fuel flow maximum positive error value (MXEF). Typical Value = 0.05.
mnef
Fuel flow maximum negative error value (MNEF). Typical Value = -0.05.
GovGAST4
Generic turbogas.
bp
Droop (bp). Typical Value = 0.05.
tv
Time constant of fuel valve positioner (Ty). Typical Value = 0.1.
ta
Maximum gate opening velocity (TA). Typical Value = 3.
tc
Maximum gate closing velocity (Tc). Typical Value = 0.5.
tcm
Fuel control time constant (Tcm). Typical Value = 0.1.
ktm
Compressor gain (Ktm). Typical Value = 0.
tm
Compressor discharge volume time constant (Tm). Typical Value = 0.2.
rymx
Maximum valve opening (RYMX). Typical Value = 1.1.
rymn
Minimum valve opening (RYMN). Typical Value = 0.
mxef
Fuel flow maximum positive error value (MXEF). Typical Value = 0.05.
mnef
Fuel flow maximum negative error value (MNEF). Typical Value = -0.05.
GovGASTWD
Woodward Gas turbine governor model.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
kdroop
(Kdroop).
kp
PID Proportional gain (Kp).
ki
Isochronous Governor Gain (Ki).
kd
Drop Governor Gain (Kd).
etd
Turbine and exhaust delay (Etd).
tcd
Compressor discharge time constant (Tcd).
trate
Turbine rating (Trate). Unit = MW.
t
Fuel Control Time Constant (T).
tmax
Maximum Turbine limit (Tmax).
tmin
Minimum Turbine limit (Tmin).
ecr
Combustion reaction time delay (Ecr).
k3
Ratio of Fuel Adjustment (K3).
a
Valve positioner (A).
b
Valve positioner (B).
c
Valve positioner (C).
tf
Fuel system time constant (Tf).
kf
Fuel system feedback (Kf).
k5
Gain of radiation shield (K5).
k4
Gain of radiation shield (K4).
t3
Radiation shield time constant (T3).
t4
Thermocouple time constant (T4).
tt
Temperature controller integration rate (Tt).
t5
Temperature control time constant (T5).
af1
Exhaust temperature Parameter (Af1).
bf1
(Bf1). Bf1 = E(1-w) where E (speed sensitivity coefficient) is 0.55 to 0.65 x Tr.
af2
Coefficient equal to 0.5(1-speed) (Af2).
bf2
Turbine Torque Coefficient Khhv (depends on heating value of fuel stream in combustion chamber) (Bf2).
cf2
Coefficient defining fuel flow where power output is 0% (Cf2). Synchronous but no output. Typically 0.23 x Khhv (23% fuel flow).
tr
Rated temperature (Tr).
k6
Minimum fuel flow (K6).
tc
Temperature control (Tc).
td
Power transducer time constant (Td).
GovHydro1
Basic Hydro turbine governor model.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
rperm
Permanent droop (R) (>0). Typical Value = 0.04.
rtemp
Temporary droop (r) (>R). Typical Value = 0.3.
tr
Washout time constant (Tr) (>0). Typical Value = 5.
tf
Filter time constant (Tf) (>0). Typical Value = 0.05.
tg
Gate servo time constant (Tg) (>0). Typical Value = 0.5.
velm
Maximum gate velocity (Vlem) (>0). Typical Value = 0.2.
gmax
Maximum gate opening (Gmax) (>0). Typical Value = 1.
gmin
Minimum gate opening (Gmin) (>=0). Typical Value = 0.
tw
Water inertia time constant (Tw) (>0). Typical Value = 1.
at
Turbine gain (At) (>0). Typical Value = 1.2.
dturb
Turbine damping factor (Dturb) (>=0). Typical Value = 0.5.
qnl
No-load flow at nominal head (qnl) (>=0). Typical Value = 0.08.
hdam
Turbine nominal head (hdam). Typical Value = 1.
GovHydro2
IEEE hydro turbine governor model represents plants with straightforward penstock configurations and hydraulic-dashpot governors.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
tg
Gate servo time constant (Tg). Typical Value = 0.5.
tp
Pilot servo valve time constant (Tp). Typical Value = 0.03.
uo
Maximum gate opening velocity (Uo). Unit = PU/sec. Typical Value = 0.1.
uc
Maximum gate closing velocity (Uc) (<0). Unit = PU/sec. Typical Value = -0.1.
pmax
Maximum gate opening (Pmax). Typical Value = 1.
pmin
Minimum gate opening; (Pmin). Typical Value = 0.
rperm
Permanent droop (Rperm). Typical Value = 0.05.
rtemp
Temporary droop (Rtemp). Typical Value = 0.5.
tr
Dashpot time constant (Tr). Typical Value = 12.
tw
Water inertia time constant (Tw). Typical Value = 2.
kturb
Turbine gain (Kturb). Typical Value = 1.
aturb
Turbine numerator multiplier (Aturb). Typical Value = -1.
bturb
Turbine denominator multiplier (Bturb). Typical Value = 0.5.
db1
Intentional deadband width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional deadband (db2). Unit = MW. Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovHydro3
Modified IEEE Hydro Governor-Turbine Model.
This model differs from that defined in the IEEE modeling guideline paper in that the limits on gate position and velocity do not permit "wind up" of the upstream signals.
mwbase
Base for power values (MWbase) (> 0). Unit = MW.
pmax
Maximum gate opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum gate opening, PU of MWbase (Pmin). Typical Value = 0.
governorControl
Governor control flag (Cflag).
true = PID control is active
false = double derivative control is active.
Typical Value = true.
rgate
Steady-state droop, PU, for governor output feedback (Rgate). Typical Value = 0.
relec
Steady-state droop, PU, for electrical power feedback (Relec). Typical Value = 0.05.
td
Input filter time constant (Td). Typical Value = 0.05.
tf
Washout time constant (Tf). Typical Value = 0.1.
tp
Gate servo time constant (Tp). Typical Value = 0.05.
velop
Maximum gate opening velocity (Velop). Unit = PU/sec. Typical Value = 0.2.
velcl
Maximum gate closing velocity (Velcl). Unit = PU/sec. Typical Value = -0.2.
k1
Derivative gain (K1). Typical Value = 0.01.
k2
Double derivative gain, if Cflag = -1 (K2). Typical Value = 2.5.
ki
Integral gain (Ki). Typical Value = 0.5.
kg
Gate servo gain (Kg). Typical Value = 2.
tt
Power feedback time constant (Tt). Typical Value = 0.2.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
tw
Water inertia time constant (Tw). Typical Value = 1.
at
Turbine gain (At). Typical Value = 1.2.
dturb
Turbine damping factor (Dturb). Typical Value = 0.2.
qnl
No-load turbine flow at nominal head (Qnl). Typical Value = 0.08.
h0
Turbine nominal head (H0). Typical Value = 1.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovHydro4
Hydro turbine and governor. Represents plants with straight-forward penstock configurations and hydraulic governors of traditional 'dashpot' type. This model can be used to represent simple, Francis, Pelton or Kaplan turbines.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
tg
Gate servo time constant (Tg) (>0). Typical Value = 0.5.
tp
Pilot servo time constant (Tp). Typical Value = 0.1.
uo
Max gate opening velocity (Uo). Typical Vlaue = 0.2.
uc
Max gate closing velocity (Uc). Typical Value = 0.2.
gmax
Maximum gate opening, PU of MWbase (Gmax). Typical Value = 1.
gmin
Minimum gate opening, PU of MWbase (Gmin). Typical Value = 0.
rperm
Permanent droop (Rperm). Typical Value = 0.05.
rtemp
Temporary droop (Rtemp). Typical Value = 0.3.
tr
Dashpot time constant (Tr) (>0). Typical Value = 5.
tw
Water inertia time constant (Tw) (>0). Typical Value = 1.
at
Turbine gain (At). Typical Value = 1.2.
dturb
Turbine damping factor (Dturb). Unit = delta P (PU of MWbase) / delta speed (PU).
Typical Value = 0.5. Typical Value Francis = 1.1, Kaplan = 1.1.
hdam
Head available at dam (hdam). Typical Value = 1.
qn1
No-load flow at nominal head (Qnl).
Typical Value = 0.08. Typical Value Francis = 0, Kaplan = 0.
db1
Intentional deadband width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
gv0
Nonlinear gain point 0, PU gv (Gv0).
Typical Value = 0. Typical Value Francis = 0.1, Kaplan = 0.1.
pgv0
Nonlinear gain point 0, PU power (Pgv0). Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1).
Typical Value = 0. Typical Value Francis = 0.4, Kaplan = 0.4.
pgv1
Nonlinear gain point 1, PU power (Pgv1).
Typical Value = 0. Typical Value Francis = 0.42, Kaplan = 0.35.
gv2
Nonlinear gain point 2, PU gv (Gv2).
Typical Value = 0. Typical Value Francis = 0.5, Kaplan = 0.5.
pgv2
Nonlinear gain point 2, PU power (Pgv2).
Typical Value = 0. Typical Value Francis = 0.56, Kaplan = 0.468.
gv3
Nonlinear gain point 3, PU gv (Gv3).
Typical Value = 0. Typical Value Francis = 0.7, Kaplan = 0.7.
pgv3
Nonlinear gain point 3, PU power (Pgv3).
Typical Value = 0. Typical Value Francis = 0.8, Kaplan = 0.796.
gv4
Nonlinear gain point 4, PU gv (Gv4).
Typical Value = 0. Typical Value Francis = 0.8, Kaplan = 0.8.
pgv4
Nonlinear gain point 4, PU power (Pgv4).
Typical Value = 0. Typical Value Francis = 0.9, Kaplan = 0.917.
gv5
Nonlinear gain point 5, PU gv (Gv5).
Typical Value = 0. Typical Value Francis = 0.9, Kaplan = 0.9.
pgv5
Nonlinear gain point 5, PU power (Pgv5).
Typical Value = 0. Typical Value Francis = 0.97, Kaplan = 0.99.
bgv0
Kaplan blade servo point 0 (Bgv0). Typical Value = 0.
bgv1
Kaplan blade servo point 1 (Bgv1). Typical Value = 0.
bgv2
Kaplan blade servo point 2 (Bgv2).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 0.1.
bgv3
Kaplan blade servo point 3 (Bgv3).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 0.667.
bgv4
Kaplan blade servo point 4 (Bgv4).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 0.9.
bgv5
Kaplan blade servo point 5 (Bgv5).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 1.
bmax
Maximum blade adjustment factor (Bmax).
Typical Value = 0. Typical Value Francis = 0, Kaplan = 1.1276.
tblade
Blade servo time constant (Tblade). Typical Value = 100.
GovHydroDD
Double derivative hydro governor and turbine.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
pmax
Maximum gate opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum gate opening, PU of MWbase (Pmin). Typical Value = 0.
r
Steady state droop (R). Typical Value = 0.05.
td
Input filter time constant (Td). Typical Value = 0.
tf
Washout time constant (Tf). Typical Value = 0.1.
tp
Gate servo time constant (Tp). Typical Value = 0.35.
velop
Maximum gate opening velocity (Velop). Unit = PU/sec. Typical Value = 0.09.
velcl
Maximum gate closing velocity (Velcl). Unit = PU/sec. Typical Value = -0.14.
k1
Single derivative gain (K1). Typical Value = 3.6.
k2
Double derivative gain (K2). Typical Value = 0.2.
ki
Integral gain (Ki). Typical Value = 1.
kg
Gate servo gain (Kg). Typical Value = 3.
tturb
Turbine time constant (Tturb) (note 3). Typical Value = 0.8.
aturb
Turbine numerator multiplier (Aturb) (note 3). Typical Value = -1.
bturb
Turbine denominator multiplier (Bturb) (note 3). Typical Value = 0.5.
tt
Power feedback time constant (Tt). Typical Value = 0.02.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
gmax
Maximum gate opening (Gmax). Typical Value = 0.
gmin
Minimum gate opening (Gmin). Typical Value = 0.
inputSignal
Input signal switch (Flag).
true = Pe input is used
false = feedback is received from CV.
Flag is normally dependent on Tt. If Tf is zero, Flag is set to false. If Tf is not zero, Flag is set to true.
Typical Value = true.
GovHydroFrancis
Detailed hydro unit - Francis model. This model can be used to represent three types of governors.
A schematic of the hydraulic system of detailed hydro unit models, like Francis and Pelton, is provided in the DetailedHydroModelHydraulicSystem diagram.
am
Opening section Seff at the maximum efficiency (Am). Typical Value = 0.7.
av0
Area of the surge tank (AV0). Unit = m2. Typical Value = 30.
Area
Area.
CIMDatatype
value
unit
multiplier
av1
Area of the compensation tank (AV1). Unit = m2. Typical Value = 700.
bp
Droop (Bp). Typical Value = 0.05.
db1
Intentional dead-band width (DB1). Unit = Hz. Typical Value = 0.
etamax
Maximum efficiency (EtaMax). Typical Value = 1.05.
governorControl
Governor control flag (Cflag). Typical Value = mechanicHydrolicTachoAccelerator.
FrancisGovernorControlKind
Governor control flag for Francis hydro model.
mechanicHydrolicTachoAccelerator
Mechanic-hydraulic regulator with tacho-accelerometer (Cflag = 1).
mechanicHydraulicTransientFeedback
Mechanic-hydraulic regulator with transient feedback (Cflag=2).
electromechanicalElectrohydraulic
Electromechanical and electrohydraulic regulator (Cflag=3).
h1
Head of compensation chamber water level with respect to the level of penstock (H1). Unit = m. Typical Value = 4.
Length
Unit of length. Never negative.
CIMDatatype
value
unit
multiplier
h2
Head of surge tank water level with respect to the level of penstock (H2). Unit = m. Typical Value = 40.
hn
Rated hydraulic head (Hn). Unit = m. Typical Value = 250.
kc
Penstock loss coefficient (due to friction) (Kc). Typical Value = 0.025.
kg
Water tunnel and surge chamber loss coefficient (due to friction) (Kg). Typical Value = 0.025.
kt
Washout gain (Kt). Typical Value = 0.25.
qc0
No-load turbine flow at nominal head (Qc0). Typical Value = 0.21.
qn
Rated flow (Qn). Unit = m3/s. Typical Value = 40.
VolumeFlowRate
Volume per time.
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
ta
Derivative gain (Ta). Typical Value = 3.
td
Washout time constant (Td). Typical Value = 3.
ts
Gate servo time constant (Ts). Typical Value = 0.5.
twnc
Water inertia time constant (Twnc). Typical Value = 1.
twng
Water tunnel and surge chamber inertia time constant (Twng). Typical Value = 3.
tx
Derivative feedback gain (Tx). Typical Value = 1.
va
Maximum gate opening velocity (Va). Unit = PU/sec. Typical Value = 0.011.
valvmax
Maximum gate opening (ValvMax). Typical Value = 1.
valvmin
Minimum gate opening (ValvMin). Typical Value = 0.
vc
Maximum gate closing velocity (Vc). Unit = PU/sec. Typical Value = -0.011.
waterTunnelSurgeChamberSimulation
Water tunnel and surge chamber simulation (Tflag).
true = enable of water tunnel and surge chamber simulation
false = inhibit of water tunnel and surge chamber simulation.
Typical Value = false.
zsfc
Head of upper water level with respect to the level of penstock (Zsfc). Unit = m. Typical Value = 25.
GovHydroPelton
Detailed hydro unit - Pelton model. This model can be used to represent the dynamic related to water tunnel and surge chamber.
A schematic of the hydraulic system of detailed hydro unit models, like Francis and Pelton, is located under the GovHydroFrancis class.
av0
Area of the surge tank (AV0). Unit = m2. Typical Value = 30.
av1
Area of the compensation tank (AV1). Unit = m2. Typical Value = 700.
bp
Droop (bp). Typical Value = 0.05.
db1
Intentional dead-band width (DB1). Unit = Hz. Typical Value = 0.
db2
Intentional dead-band width of valve opening error (DB2). Unit = Hz. Typical Value = 0.01.
h1
Head of compensation chamber water level with respect to the level of penstock (H1). Unit = m. Typical Value = 4.
h2
Head of surge tank water level with respect to the level of penstock (H2). Unit = m. Typical Value = 40.
hn
Rated hydraulic head (Hn). Unit = m. Typical Value = 250.
kc
Penstock loss coefficient (due to friction) (Kc). Typical Value = 0.025.
kg
Water tunnel and surge chamber loss coefficient (due to friction) (Kg). Typical Value = -0.025.
qc0
No-load turbine flow at nominal head (Qc0). Typical Value = 0.05.
qn
Rated flow (Qn). Unit = m3/s. Typical Value = 40.
simplifiedPelton
Simplified Pelton model simulation (Sflag).
true = enable of simplified Pelton model simulation
false = enable of complete Pelton model simulation (non linear gain).
Typical Value = false.
staticCompensating
Static compensating characteristic (Cflag).
true = enable of static compensating characteristic
false = inhibit of static compensating characteristic.
Typical Value = false.
ta
Derivative gain (accelerometer time constant) (Ta). Typical Value = 3.
ts
Gate servo time constant (Ts). Typical Value = 0.15.
tv
Servomotor integrator time constant (TV). Typical Value = 0.3.
twnc
Water inertia time constant (Twnc). Typical Value = 1.
twng
Water tunnel and surge chamber inertia time constant (Twng). Typical Value = 3.
tx
Electronic integrator time constant (Tx). Typical Value = 0.5.
va
Maximum gate opening velocity (Va). Unit = PU/sec. Typical Value = 0.016.
valvmax
Maximum gate opening (ValvMax). Typical Value = 1.
valvmin
Minimum gate opening (ValvMin). Typical Value = 0.
vav
Maximum servomotor valve opening velocity (Vav). Typical Value = 0.017.
vc
Maximum gate closing velocity (Vc). Unit = PU/sec. Typical Value = -0.016.
vcv
Maximum servomotor valve closing velocity (Vcv). Typical Value = -0.017.
waterTunnelSurgeChamberSimulation
Water tunnel and surge chamber simulation (Tflag).
true = enable of water tunnel and surge chamber simulation
false = inhibit of water tunnel and surge chamber simulation.
Typical Value = false.
zsfc
Head of upper water level with respect to the level of penstock (Zsfc). Unit = m. Typical Value = 25.
GovHydroPID
PID governor and turbine.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
pmax
Maximum gate opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum gate opening, PU of MWbase (Pmin). Typical Value = 0.
r
Steady state droop (R). Typical Value = 0.05.
td
Input filter time constant (Td). Typical Value = 0.
tf
Washout time constant (Tf). Typical Value = 0.1.
tp
Gate servo time constant (Tp). Typical Value = 0.35.
velop
Maximum gate opening velocity (Velop). Unit = PU/sec. Typical Value = 0.09.
velcl
Maximum gate closing velocity (Velcl). Unit = PU/sec. Typical Value = -0.14.
kd
Derivative gain (Kd). Typical Value = 1.11.
kp
Proportional gain (Kp). Typical Value = 0.1.
ki
Integral gain (Ki). Typical Value = 0.36.
kg
Gate servo gain (Kg). Typical Value = 2.5.
tturb
Turbine time constant (Tturb) (note 3). Typical Value = 0.8.
aturb
Turbine numerator multiplier (Aturb) (note 3). Typical Value -1.
bturb
Turbine denominator multiplier (Bturb) (note 3). Typical Value = 0.5.
tt
Power feedback time constant (Tt). Typical Value = 0.02.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
inputSignal
Input signal switch (Flag).
true = Pe input is used
false = feedback is received from CV.
Flag is normally dependent on Tt. If Tf is zero, Flag is set to false. If Tf is not zero, Flag is set to true. Typical Value = true.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovHydroPID2
Hydro turbine and governor. Represents plants with straight forward penstock configurations and "three term" electro-hydraulic governors (i.e. Woodard electronic).
mwbase
Base for power values (MWbase) (>0). Unit = MW.
treg
Speed detector time constant (Treg). Typical Value = 0.
rperm
Permanent drop (Rperm). Typical Value = 0.
kp
Proportional gain (Kp). Typical Value = 0.
ki
Reset gain (Ki). Unit = PU/ sec. Typical Value = 0.
kd
Derivative gain (Kd). Typical Value = 0.
ta
Controller time constant (Ta) (>0). Typical Value = 0.
tb
Gate servo time constant (Tb) (>0). Typical Value = 0.
velmax
Maximum gate opening velocity (Velmax). Unit = PU/sec. Typical Value = 0.
velmin
Maximum gate closing velocity (Velmin). Unit = PU/sec. Typical Value = 0.
gmax
Maximum gate opening (Gmax). Typical Value = 0.
gmin
Minimum gate opening (Gmin). Typical Value = 0.
tw
Water inertia time constant (Tw) (>0). Typical Value = 0.
d
Turbine damping factor (D). Unit = delta P / delta speed. Typical Value = 0.
g0
Gate opening at speed no load (G0). Typical Value = 0.
g1
Intermediate gate opening (G1). Typical Value = 0.
p1
Power at gate opening G1 (P1). Typical Value = 0.
g2
Intermediate gate opening (G2). Typical Value = 0.
p2
Power at gate opening G2 (P2). Typical Value = 0.
p3
Power at full opened gate (P3). Typical Value = 0.
atw
Factor multiplying Tw (Atw). Typical Value = 0.
feedbackSignal
Feedback signal type flag (Flag).
true = use gate position feedback signal
false = use Pe.
GovHydroR
Fourth order lead-lag governor and hydro turbine.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
pmax
Maximum gate opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum gate opening, PU of MWbase (Pmin). Typical Value = 0.
r
Steady-state droop (R). Typical Value = 0.05.
td
Input filter time constant (Td). Typical Value = 0.05.
t1
Lead time constant 1 (T1). Typical Value = 1.5.
t2
Lag time constant 1 (T2). Typical Value = 0.1.
t3
Lead time constant 2 (T3). Typical Value = 1.5.
t4
Lag time constant 2 (T4). Typical Value = 0.1.
t5
Lead time constant 3 (T5). Typical Value = 0.
t6
Lag time constant 3 (T6). Typical Value = 0.05.
t7
Lead time constant 4 (T7). Typical Value = 0.
t8
Lag time constant 4 (T8). Typical Value = 0.05.
tp
Gate servo time constant (Tp). Typical Value = 0.05.
velop
Maximum gate opening velocity (Velop). Unit = PU/sec. Typical Value = 0.2.
velcl
Maximum gate closing velocity (Velcl). Unit = PU/sec. Typical Value = -0.2.
ki
Integral gain (Ki). Typical Value = 0.5.
kg
Gate servo gain (Kg). Typical Value = 2.
gmax
Maximum governor output (Gmax). Typical Value = 1.05.
gmin
Minimum governor output (Gmin). Typical Value = -0.05.
tt
Power feedback time constant (Tt). Typical Value = 0.
inputSignal
Input signal switch (Flag).
true = Pe input is used
false = feedback is received from CV.
Flag is normally dependent on Tt. If Tf is zero, Flag is set to false. If Tf is not zero, Flag is set to true. Typical Value = true.
db1
Intentional dead-band width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
db2
Unintentional dead-band (db2). Unit = MW. Typical Value = 0.
tw
Water inertia time constant (Tw). Typical Value = 1.
at
Turbine gain (At). Typical Value = 1.2.
dturb
Turbine damping factor (Dturb). Typical Value = 0.2.
qnl
No-load turbine flow at nominal head (Qnl). Typical Value = 0.08.
h0
Turbine nominal head (H0). Typical Value = 1.
gv1
Nonlinear gain point 1, PU gv (Gv1). Typical Value = 0.
pgv1
Nonlinear gain point 1, PU power (Pgv1). Typical Value = 0.
gv2
Nonlinear gain point 2, PU gv (Gv2). Typical Value = 0.
pgv2
Nonlinear gain point 2, PU power (Pgv2). Typical Value = 0.
gv3
Nonlinear gain point 3, PU gv (Gv3). Typical Value = 0.
pgv3
Nonlinear gain point 3, PU power (Pgv3). Typical Value = 0.
gv4
Nonlinear gain point 4, PU gv (Gv4). Typical Value = 0.
pgv4
Nonlinear gain point 4, PU power (Pgv4). Typical Value = 0.
gv5
Nonlinear gain point 5, PU gv (Gv5). Typical Value = 0.
pgv5
Nonlinear gain point 5, PU power (Pgv5). Typical Value = 0.
gv6
Nonlinear gain point 6, PU gv (Gv6). Typical Value = 0.
pgv6
Nonlinear gain point 6, PU power (Pgv6). Typical Value = 0.
GovHydroWEH
Woodward Electric Hydro Governor Model.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
rpg
Permanent droop for governor output feedback (R-Perm-Gate).
rpp
Permanent droop for electrical power feedback (R-Perm-Pe).
tpe
Electrical power droop time constant (Tpe).
kp
Derivative control gain (Kp).
ki
Derivative controller Integral gain (Ki).
kd
Derivative controller derivative gain (Kd).
td
Derivative controller time constant to limit the derivative characteristic beyond a breakdown frequency to avoid amplification of high-frequency noise (Td).
tp
Pilot Valve time lag time constant (Tp).
tdv
Distributive Valve time lag time constant (Tdv).
tg
Value to allow the Distribution valve controller to advance beyond the gate movement rate limit (Tg).
gtmxop
Maximum gate opening rate (Gtmxop).
gtmxcl
Maximum gate closing rate (Gtmxcl).
gmax
Maximum Gate Position (Gmax).
gmin
Minimum Gate Position (Gmin).
dturb
Turbine damping factor (Dturb). Unit = delta P (PU of MWbase) / delta speed (PU).
tw
Water inertia time constant (Tw) (>0).
db
Speed Dead Band (db).
dpv
Value to allow the Pilot valve controller to advance beyond the gate limits (Dpv).
dicn
Value to allow the integral controller to advance beyond the gate limits (Dicn).
feedbackSignal
Feedback signal selection (Sw).
true = PID Output (if R-Perm-Gate=droop and R-Perm-Pe=0)
false = Electrical Power (if R-Perm-Gate=0 and R-Perm-Pe=droop) or
false = Gate Position (if R-Perm-Gate=droop and R-Perm-Pe=0).
gv1
Gate 1 (Gv1). Gate Position value for point 1 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
gv2
Gate 2 (Gv2). Gate Position value for point 2 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
gv3
Gate 3 (Gv3). Gate Position value for point 3 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
gv4
Gate 4 (Gv4). Gate Position value for point 4 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
gv5
Gate 5 (Gv5). Gate Position value for point 5 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl1
Flow Gate 1 (Fl1). Flow value for gate position point 1 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl2
Flow Gate 2 (Fl2). Flow value for gate position point 2 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl3
Flow Gate 3 (Fl3). Flow value for gate position point 3 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl4
Flow Gate 4 (Fl4). Flow value for gate position point 4 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fl5
Flow Gate 5 (Fl5). Flow value for gate position point 5 for lookup table representing water flow through the turbine as a function of gate position to produce steady state flow.
fp1
Flow P1 (Fp1). Turbine Flow value for point 1 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp2
Flow P2 (Fp2). Turbine Flow value for point 2 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp3
Flow P3 (Fp3). Turbine Flow value for point 3 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp4
Flow P4 (Fp4). Turbine Flow value for point 4 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp5
Flow P5 (Fp5). Turbine Flow value for point 5 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp6
Flow P6 (Fp6). Turbine Flow value for point 6 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp7
Flow P7 (Fp7). Turbine Flow value for point 7 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp8
Flow P8 (Fp8). Turbine Flow value for point 8 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp9
Flow P9 (Fp9). Turbine Flow value for point 9 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
fp10
Flow P10 (Fp10). Turbine Flow value for point 10 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss1
Pmss Flow P1 (Pmss1). Mechanical Power output Pmss for Turbine Flow point 1 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss2
Pmss Flow P2 (Pmss2). Mechanical Power output Pmss for Turbine Flow point 2 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss3
Pmss Flow P3 (Pmss3). Mechanical Power output Pmss for Turbine Flow point 3 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss4
Pmss Flow P4 (Pmss4). Mechanical Power output Pmss for Turbine Flow point 4 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss5
Pmss Flow P5 (Pmss5). Mechanical Power output Pmss for Turbine Flow point 5 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss6
Pmss Flow P6 (Pmss6). Mechanical Power output Pmss for Turbine Flow point 6 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss7
Pmss Flow P7 (Pmss7). Mechanical Power output Pmss for Turbine Flow point 7 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss8
Pmss Flow P8 (Pmss8). Mechanical Power output Pmss for Turbine Flow point 8 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss9
Pmss Flow P9 (Pmss9). Mechanical Power output Pmss for Turbine Flow point 9 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
pmss10
Pmss Flow P10 (Pmss10). Mechanical Power output Pmss for Turbine Flow point 10 for lookup table representing per unit mechanical power on machine MVA rating as a function of turbine flow.
GovHydroWPID
Woodward PID Hydro Governor.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
treg
Speed detector time constant (Treg).
reg
Permanent drop (Reg).
kp
Proportional gain (Kp). Typical Value = 0.1.
ki
Reset gain (Ki). Typical Value = 0.36.
kd
Derivative gain (Kd). Typical Value = 1.11.
ta
Controller time constant (Ta) (>0). Typical Value = 0.
tb
Gate servo time constant (Tb) (>0). Typical Value = 0.
velmax
Maximum gate opening velocity (Velmax). Unit = PU/sec. Typical Value = 0.
velmin
Maximum gate closing velocity (Velmin). Unit = PU/sec. Typical Value = 0.
gatmax
Gate opening Limit Maximum (Gatmax).
gatmin
Gate opening Limit Minimum (Gatmin).
tw
Water inertia time constant (Tw) (>0). Typical Value = 0.
pmax
Maximum Power Output (Pmax).
pmin
Minimum Power Output (Pmin).
d
Turbine damping factor (D). Unit = delta P / delta speed.
gv3
Gate position 3 (Gv3).
gv1
Gate position 1 (Gv1).
pgv1
Output at Gv1 PU of MWbase (Pgv1).
gv2
Gate position 2 (Gv2).
pgv2
Output at Gv2 PU of MWbase (Pgv2).
pgv3
Output at Gv3 PU of MWbase (Pgv3).
GovSteam0
A simplified steam turbine governor model.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
r
Permanent droop (R). Typical Value = 0.05.
t1
Steam bowl time constant (T1). Typical Value = 0.5.
vmax
Maximum valve position, PU of mwcap (Vmax). Typical Value = 1.
vmin
Minimum valve position, PU of mwcap (Vmin). Typical Value = 0.
t2
Numerator time constant of T2/T3 block (T2). Typical Value = 3.
t3
Reheater time constant (T3). Typical Value = 10.
dt
Turbine damping coefficient (Dt). Unit = delta P / delta speed. Typical Value = 0.
GovSteam1
Steam turbine governor model, based on the GovSteamIEEE1 model (with optional deadband and nonlinear valve gain added).
mwbase
Base for power values (MWbase) (>0). Unit = MW.
k
Governor gain (reciprocal of droop) (K) (>0). Typical Value = 25.
t1
Governor lag time constant (T1). Typical Value = 0.
t2
Governor lead time constant (T2). Typical Value = 0.
t3
Valve positioner time constant (T3) (>0). Typical Value = 0.1.
uo
Maximum valve opening velocity (Uo) (>0). Unit = PU/sec. Typical Value = 1.
uc
Maximum valve closing velocity (Uc) (<0). Unit = PU/sec. Typical Value = -10.
pmax
Maximum valve opening (Pmax) (> Pmin). Typical Value = 1.
pmin
Minimum valve opening (Pmin) (>=0). Typical Value = 0.
t4
Inlet piping/steam bowl time constant (T4). Typical Value = 0.3.
k1
Fraction of HP shaft power after first boiler pass (K1). Typical Value = 0.2.
k2
Fraction of LP shaft power after first boiler pass (K2). Typical Value = 0.
t5
Time constant of second boiler pass (T5). Typical Value = 5.
k3
Fraction of HP shaft power after second boiler pass (K3). Typical Value = 0.3.
k4
Fraction of LP shaft power after second boiler pass (K4). Typical Value = 0.
t6
Time constant of third boiler pass (T6). Typical Value = 0.5.
k5
Fraction of HP shaft power after third boiler pass (K5). Typical Value = 0.5.
k6
Fraction of LP shaft power after third boiler pass (K6). Typical Value = 0.
t7
Time constant of fourth boiler pass (T7). Typical Value = 0.
k7
Fraction of HP shaft power after fourth boiler pass (K7). Typical Value = 0.
k8
Fraction of LP shaft power after fourth boiler pass (K8). Typical Value = 0.
db1
Intentional deadband width (db1). Unit = Hz. Typical Value = 0.
eps
Intentional db hysteresis (eps). Unit = Hz. Typical Value = 0.
sdb1
Intentional deadband indicator.
true = intentional deadband is applied
false = intentional deadband is not applied.
Typical Value = true.
sdb2
Unintentional deadband location.
true = intentional deadband is applied before point "A"
false = intentional deadband is applied after point "A".
Typical Value = true.
db2
Unintentional deadband (db2). Unit = MW. Typical Value = 0.
valve
Nonlinear valve characteristic.
true = nonlinear valve characteristic is used
false = nonlinear valve characteristic is not used.
Typical Value = true.
gv1
Nonlinear gain valve position point 1 (GV1). Typical Value = 0.
pgv1
Nonlinear gain power value point 1 (Pgv1). Typical Value = 0.
gv2
Nonlinear gain valve position point 2 (GV2). Typical Value = 0.4.
pgv2
Nonlinear gain power value point 2 (Pgv2). Typical Value = 0.75.
gv3
Nonlinear gain valve position point 3 (GV3). Typical Value = 0.5.
pgv3
Nonlinear gain power value point 3 (Pgv3). Typical Value = 0.91.
gv4
Nonlinear gain valve position point 4 (GV4). Typical Value = 0.6.
pgv4
Nonlinear gain power value point 4 (Pgv4). Typical Value = 0.98.
gv5
Nonlinear gain valve position point 5 (GV5). Typical Value = 1.
pgv5
Nonlinear gain power value point 5 (Pgv5). Typical Value = 1.
gv6
Nonlinear gain valve position point 6 (GV6). Typical Value = 0.
pgv6
Nonlinear gain power value point 6 (Pgv6). Typical Value = 0.
GovSteam2
Simplified governor model.
k
Governor gain (reciprocal of droop) (K). Typical Value = 20.
dbf
Frequency dead band (DBF). Typical Value = 0.
t1
Governor lag time constant (T1) (>0). Typical Value = 0.45.
t2
Governor lead time constant (T2) (may be 0). Typical Value = 0.
pmax
Maximum fuel flow (PMAX). Typical Value = 1.
pmin
Minimum fuel flow (PMIN). Typical Value = 0.
mxef
Fuel flow maximum positive error value (MXEF). Typical Value = 1.
mnef
Fuel flow maximum negative error value (MNEF). Typical Value = -1.
GovSteamCC
Cross compound turbine governor model.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
pmaxhp
Maximum HP value position (Pmaxhp). Typical Value = 1.
rhp
HP governor droop (Rhp). Typical Value = 0.05.
t1hp
HP governor time constant (T1hp). Typical Value = 0.1.
t3hp
HP turbine time constant (T3hp). Typical Value = 0.1.
t4hp
HP turbine time constant (T4hp). Typical Value = 0.1.
t5hp
HP reheater time constant (T5hp). Typical Value = 10.
fhp
Fraction of HP power ahead of reheater (Fhp). Typical Value = 0.3.
dhp
HP damping factor (Dhp). Typical Value = 0.
pmaxlp
Maximum LP value position (Pmaxlp). Typical Value = 1.
rlp
LP governor droop (Rlp). Typical Value = 0.05.
t1lp
LP governor time constant (T1lp). Typical Value = 0.1.
t3lp
LP turbine time constant (T3lp). Typical Value = 0.1.
t4lp
LP turbine time constant (T4lp). Typical Value = 0.1.
t5lp
LP reheater time constant (T5lp). Typical Value = 10.
flp
Fraction of LP power ahead of reheater (Flp). Typical Value = 0.7.
dlp
LP damping factor (Dlp). Typical Value = 0.
GovSteamEU
Simplified model of boiler and steam turbine with PID governor.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
tp
Power transducer time constant (Tp). Typical Value = 0.07.
ke
Gain of the power controller (Ke). Typical Value = 0.65.
tip
Integral time constant of the power controller (Tip). Typical Value = 2.
tdp
Derivative time constant of the power controller (Tdp). Typical Value = 0.
tfp
Time constant of the power controller (Tfp). Typical Value = 0.
tf
Frequency transducer time constant (Tf). Typical Value = 0.
kfcor
Gain of the frequency corrector (Kfcor). Typical Value = 20.
db1
Dead band of the frequency corrector (db1). Typical Value = 0.
wfmax
Upper limit for frequency correction (Wfmax). Typical Value = 0.05.
wfmin
Lower limit for frequency correction (Wfmin). Typical Value = -0.05.
pmax
Maximal active power of the turbine (Pmax). Typical Value = 1.
ten
Electro hydraulic transducer (Ten). Typical Value = 0.1.
tw
Speed transducer time constant (Tw). Typical Value = 0.02.
kwcor
Gain of the speed governor (Kwcor). Typical Value = 20.
db2
Dead band of the speed governor (db2). Typical Value = 0.0004.
wwmax
Upper limit for the speed governor (Wwmax). Typical Value = 0.1.
wwmin
Lower limit for the speed governor frequency correction (Wwmin). Typical Value = -1.
wmax1
Emergency speed control lower limit (wmax1). Typical Value = 1.025.
wmax2
Emergency speed control upper limit (wmax2). Typical Value = 1.05.
tvhp
Control valves servo time constant (Tvhp). Typical Value = 0.1.
cho
Control valves rate opening limit (Cho). Unit = PU/sec. Typical Value = 0.17.
chc
Control valves rate closing limit (Chc). Unit = PU/sec. Typical Value = -3.3.
hhpmax
Maximum control valve position (Hhpmax). Typical Value = 1.
tvip
Intercept valves servo time constant (Tvip). Typical Value = 0.15.
cio
Intercept valves rate opening limit (Cio). Typical Value = 0.123.
cic
Intercept valves rate closing limit (Cic). Typical Value = -2.2.
simx
Intercept valves transfer limit (Simx). Typical Value = 0.425.
thp
High pressure (HP) time constant of the turbine (Thp). Typical Value = 0.31.
trh
Reheater time constant of the turbine (Trh). Typical Value = 8.
tlp
Low pressure(LP) time constant of the turbine (Tlp). Typical Value = 0.45.
prhmax
Maximum low pressure limit (Prhmax). Typical Value = 1.4.
khp
Fraction of total turbine output generated by HP part (Khp). Typical Value = 0.277.
klp
Fraction of total turbine output generated by HP part (Klp). Typical Value = 0.723.
tb
Boiler time constant (Tb). Typical Value = 100.
GovSteamFV2
Steam turbine governor with reheat time constants and modeling of the effects of fast valve closing to reduce mechanical power.
mwbase
Alternate Base used instead of Machine base in equipment model if necessary (MWbase) (>0). Unit = MW.
r
(R).
t1
Governor time constant (T1).
vmax
(Vmax).
vmin
(Vmin).
k
Fraction of the turbine power developed by turbine sections not involved in fast valving (K).
t3
Reheater time constant (T3).
dt
(Dt).
tt
Time constant with which power falls off after intercept valve closure (Tt).
ta
Time after initial time for valve to close (Ta).
tb
Time after initial time for valve to begin opening (Tb).
tc
Time after initial time for valve to become fully open (Tc).
ti
Initial time to begin fast valving (Ti).
GovSteamFV3
Simplified GovSteamIEEE1 Steam turbine governor model with Prmax limit and fast valving.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
k
Governor gain, (reciprocal of droop) (K). Typical Value = 20.
t1
Governor lead time constant (T1). Typical Value = 0.
t2
Governor lag time constant (T2). Typical Value = 0.
t3
Valve positioner time constant (T3). Typical Value = 0.
uo
Maximum valve opening velocity (Uo). Unit = PU/sec. Typical Value = 0.1.
uc
Maximum valve closing velocity (Uc). Unit = PU/sec. Typical Value = -1.
pmax
Maximum valve opening, PU of MWbase (Pmax). Typical Value = 1.
pmin
Minimum valve opening, PU of MWbase (Pmin). Typical Value = 0.
t4
Inlet piping/steam bowl time constant (T4). Typical Value = 0.2.
k1
Fraction of turbine power developed after first boiler pass (K1). Typical Value = 0.2.
t5
Time constant of second boiler pass (i.e. reheater) (T5). Typical Value = 0.5.
k2
Fraction of turbine power developed after second boiler pass (K2). Typical Value = 0.2.
t6
Time constant of crossover or third boiler pass (T6). Typical Value = 10.
k3
Fraction of hp turbine power developed after crossover or third boiler pass (K3). Typical Value = 0.6.
ta
Time to close intercept valve (IV) (Ta). Typical Value = 0.97.
tb
Time until IV starts to reopen (Tb). Typical Value = 0.98.
tc
Time until IV is fully open (Tc). Typical Value = 0.99.
prmax
Max. pressure in reheater (Prmax). Typical Value = 1.
GovSteamFV4
Detailed electro-hydraulic governor for steam unit.
kf1
Frequency bias (reciprocal of droop) (Kf1). Typical Value = 20.
kf3
Frequency control (reciprocal of droop) (Kf3). Typical Value = 20.
lps
Maximum positive power error (Lps). Typical Value = 0.03.
lpi
Maximum negative power error (Lpi). Typical Value = -0.15.
mxef
Upper limit for frequency correction (MXEF). Typical Value = 0.05.
mnef
Lower limit for frequency correction (MNEF). Typical Value = -0.05.
crmx
Maximum value of regulator set-point (Crmx). Typical Value = 1.2.
crmn
Minimum value of regulator set-point (Crmn). Typical Value = 0.
kpt
Proportional gain of electro-hydraulic regulator (Kpt). Typical Value = 0.3.
kit
Integral gain of electro-hydraulic regulator (Kit). Typical Value = 0.04.
rvgmx
Maximum value of integral regulator (Rvgmx). Typical Value = 1.2.
rvgmn
Minimum value of integral regulator (Rvgmn). Typical Value = 0.
svmx
Maximum regulator gate opening velocity (Svmx). Typical Value = 0.0333.
svmn
Maximum regulator gate closing velocity (Svmn). Typical Value = -0.0333.
srmx
Maximum valve opening (Srmx). Typical Value = 1.1.
srmn
Minimum valve opening (Srmn). Typical Value = 0.
kpp
Proportional gain of pressure feedback regulator (Kpp). Typical Value = 1.
kip
Integral gain of pressure feedback regulator (Kip). Typical Value = 0.5.
rsmimx
Maximum value of integral regulator (Rsmimx). Typical Value = 1.1.
rsmimn
Minimum value of integral regulator (Rsmimn). Typical Value = 0.
kmp1
First gain coefficient of intercept valves characteristic (Kmp1). Typical Value = 0.5.
kmp2
Second gain coefficient of intercept valves characteristic (Kmp2). Typical Value = 3.5.
srsmp
Intercept valves characteristic discontinuity point (Srsmp). Typical Value = 0.43.
ta
Control valves rate opening time (Ta). Typical Value = 0.8.
tc
Control valves rate closing time (Tc). Typical Value = 0.5.
ty
Control valves servo time constant (Ty). Typical Value = 0.1.
yhpmx
Maximum control valve position (Yhpmx). Typical Value = 1.1.
yhpmn
Minimum control valve position (Yhpmn). Typical Value = 0.
tam
Intercept valves rate opening time (Tam). Typical Value = 0.8.
tcm
Intercept valves rate closing time (Tcm). Typical Value = 0.5.
ympmx
Maximum intercept valve position (Ympmx). Typical Value = 1.1.
ympmn
Minimum intercept valve position (Ympmn). Typical Value = 0.
y
Coefficient of linearized equations of turbine (Stodola formulation) (Y). Typical Value = 0.13.
thp
High pressure (HP) time constant of the turbine (Thp). Typical Value = 0.15.
trh
Reheater time constant of the turbine (Trh). Typical Value = 10.
tmp
Low pressure (LP) time constant of the turbine (Tmp). Typical Value = 0.4.
khp
Fraction of total turbine output generated by HP part (Khp). Typical Value = 0.35.
pr1
First value of pressure set point static characteristic (Pr1). Typical Value = 0.2.
pr2
Second value of pressure set point static characteristic, corresponding to Ps0 = 1.0 PU (Pr2). Typical Value = 0.75.
psmn
Minimum value of pressure set point static characteristic (Psmn). Typical Value = 1.
kpc
Proportional gain of pressure regulator (Kpc). Typical Value = 0.5.
kic
Integral gain of pressure regulator (Kic). Typical Value = 0.0033.
kdc
Derivative gain of pressure regulator (Kdc). Typical Value = 1.
tdc
Derivative time constant of pressure regulator (Tdc). Typical Value = 90.
cpsmx
Maximum value of pressure regulator output (Cpsmx). Typical Value = 1.
cpsmn
Minimum value of pressure regulator output (Cpsmn). Typical Value = -1.
krc
Maximum variation of fuel flow (Krc). Typical Value = 0.05.
tf1
Time constant of fuel regulation (Tf1). Typical Value = 10.
tf2
Time constant of steam chest (Tf2). Typical Value = 10.
tv
Boiler time constant (Tv). Typical Value = 60.
ksh
Pressure loss due to flow friction in the boiler tubes (Ksh). Typical Value = 0.08.
GovSteamSGO
Simplified Steam turbine governor model.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
t1
Controller lag (T1).
t2
Controller lead compensation (T2).
t3
Governor lag (T3) (>0).
t4
Delay due to steam inlet volumes associated with steam chest and inlet piping (T4).
t5
Reheater delay including hot and cold leads (T5).
t6
Delay due to IP-LP turbine, crossover pipes and LP end hoods (T6).
k1
One/per unit regulation (K1).
k2
Fraction (K2).
k3
Fraction (K3).
pmax
Upper power limit (Pmax).
pmin
Lower power limit (Pmin).
TurbineLoadControllerDynamics
A turbine load controller acts to maintain turbine power at a set value by continuous adjustment of the turbine governor speed-load reference.
TurbineLoadControllerDynamics
Turbine load controller function block whose behavior is described by reference to a standard model or by definition of a user-defined model.
abstract
TurbLCFB1
Turbine Load Controller model developed in the WECC. This model represents a supervisory turbine load controller that acts to maintain turbine power at a set value by continuous adjustment of the turbine governor speed-load reference. This model is intended to represent slow reset 'outer loop' controllers managing the action of the turbine governor.
mwbase
Base for power values (MWbase) (>0). Unit = MW.
speedReferenceGovernor
Type of turbine governor reference (Type).
true = speed reference governor
false = load reference governor.
Typical Value = true.
db
Controller dead band (db). Typical Value = 0.
emax
Maximum control error (Emax) (note 4). Typical Value = 0.02.
fb
Frequency bias gain (Fb). Typical Value = 0.
kp
Proportional gain (Kp). Typical Value = 0.
ki
Integral gain (Ki). Typical Value = 0.
fbf
Frequency bias flag (Fbf).
true = enable frequency bias
false = disable frequency bias.
Typical Value = false.
pbf
Power controller flag (Pbf).
true = enable load controller
false = disable load controller.
Typical Value = false.
tpelec
Power transducer time constant (Tpelec). Typical Value = 0.
irmax
Maximum turbine speed/load reference bias (Irmax) (note 3). Typical Value = 0.
pmwset
Power controller setpoint (Pmwset) (note 1). Unit = MW. Typical Value = 0.
MechanicalLoadDynamics
A mechanical load represents the variation in a motor's shaft torque or power as a function of shaft speed.
MechanicalLoadDynamics
Mechanical load function block whose behavior is described by reference to a standard model or by definition of a user-defined model.
abstract
MechLoad1
Mechanical load model type 1.
a
Speed squared coefficient (a).
b
Speed coefficient (b).
d
Speed to the exponent coefficient (d).
e
Exponent (e).
ExcitationSystemDynamics
The excitation system model provides the field voltage (Efd) for a synchronous machine model. It is linked to a specific generator (synchronous machine). The data parameters are different for each excitation system model; the same parameter name may have different meaning in different models.
ExcIEEEST1AUELselectorKind
Type of connection for the UEL input used in ExcIEEEST1A.
ignoreUELsignal
Ignore UEL signal.
inputHVgateVoltageOutput
UEL input HV gate with voltage regulator output.
inputHVgateErrorSignal
UEL input HV gate with error signal.
inputAddedToErrorSignal
UEL input added to error signal.
ExcREXSFeedbackSignalKind
Type of rate feedback signals.
fieldVoltage
The voltage regulator output voltage is used. It is the same as exciter field voltage.
fieldCurrent
The exciter field current is used.
outputVoltage
The output voltage of the exciter is used.
ExcST6BOELselectorKind
Type of connection for the OEL input used for static excitation systems type 6B.
noOELinput
No OEL input is used.
beforeUEL
The connection is before UEL.
afterUEL
The connection is after UEL.
ExcST7BOELselectorKind
Type of connection for the OEL input used for static excitation systems type 7B.
noOELinput
No OEL input is used.
addVref
The signal is added to Vref.
inputLVgate
The signal is connected in the input of the LV gate.
outputLVgate
The signal is connected in the output of the LV gate.
ExcST7BUELselectorKind
Type of connection for the UEL input used for static excitation systems type 7B.
noUELinput
No UEL input is used.
addVref
The signal is added to Vref.
inputHVgate
The signal is connected in the input of the HV gate.
outputHVgate
The signal is connected in the output of the HV gate.
ExcitationSystemDynamics
Excitation system function block whose behavior is described by reference to a standard model or by definition of a user-defined model.
abstract
ExcitationSystemDynamics
Excitation system model with which this power system stabilizer model is associated.
Yes
PowerSystemStabilizerDynamics
Power system stabilizer model associated with this excitation system model.
PowerSystemStabilizerDynamics
No
ExcitationSystemDynamics
Excitation system model with which this Power Factor or VAr controller Type I model is associated.
Yes
PFVArControllerType1Dynamics
Power Factor or VAr controller Type I model associated with this excitation system model.
PFVArControllerType1Dynamics
No
ExcitationSystemDynamics
Excitation system model with which this voltage compensator is associated.
Yes
VoltageCompensatorDynamics
Voltage compensator model associated with this excitation system model.
VoltageCompensatorDynamics
No
ExcitationSystemDynamics
Excitation system model with which this discontinuous excitation control model is associated.
Yes
DiscontinuousExcitationControlDynamics
Discontinuous excitation control model associated with this excitation system model.
DiscontinuousExcitationControlDynamics
No
ExcitationSystemDynamics
Excitation system model with which this underexcitation limiter model is associated.
Yes
UnderexcitationLimiterDynamics
Undrexcitation limiter model associated with this excitation system model.
UnderexcitationLimiterDynamics
No
ExcitationSystemDynamics
Excitation system model with which this Power Factor or VAr controller Type II is associated.
Yes
PFVArControllerType2Dynamics
Power Factor or VAr controller Type II model associated with this excitation system model.
PFVArControllerType2Dynamics
No
ExcitationSystemDynamics
Excitation system model with which this overexcitation limiter model is associated.
Yes
OverexcitationLimiterDynamics
Overexcitation limiter model associated with this excitation system model.
OverexcitationLimiterDynamics
No
ExcIEEEAC1A
The class represents IEEE Std 421.5-2005 type AC1A model. The model represents the field-controlled alternator-rectifier excitation systems designated Type AC1A. These excitation systems consist of an alternator main exciter with non-controlled rectifiers.
Reference: IEEE Standard 421.5-2005 Section 6.1.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 400.
ta
Voltage regulator time constant (TA). Typical Value = 0.02.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 14.5.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -14.5.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.8.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.03.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.2.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 0.38.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1). Typical Value = 4.18.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.1.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 3.14.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.03.
vrmax
Maximum voltage regulator outputs (VRMAX). Typical Value = 6.03.
vrmin
Minimum voltage regulator outputs (VRMIN). Typical Value = -5.43.
ExcIEEEAC2A
The class represents IEEE Std 421.5-2005 type AC2A model. The model represents a high initial response field-controlled alternator-rectifier excitation system. The alternator main exciter is used with non-controlled rectifiers. The Type AC2A model is similar to that of Type AC1A except for the inclusion of exciter time constant compensation and exciter field current limiting elements.
Reference: IEEE Standard 421.5-2005 Section 6.2.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 400.
ta
Voltage regulator time constant (TA). Typical Value = 0.02.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 8.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -8.
kb
Second stage regulator gain (KB). Typical Value = 25.
vrmax
Maximum voltage regulator outputs (VRMAX). Typical Value = 105.
vrmin
Minimum voltage regulator outputs (VRMIN). Typical Value = -95.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.6.
vfemax
Exciter field current limit reference (VFEMAX). Typical Value = 4.4.
kh
Exciter field current feedback gain (KH). Typical Value = 1.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.03.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.28.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 0.35.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1). Typical Value = 4.4.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.037.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 3.3.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.012.
ExcIEEEAC3A
The class represents IEEE Std 421.5-2005 type AC3A model. The model represents the field-controlled alternator-rectifier excitation systems designated Type AC3A. These excitation systems include an alternator main exciter with non-controlled rectifiers. The exciter employs self-excitation, and the voltage regulator power is derived from the exciter output voltage. Therefore, this system has an additional nonlinearity, simulated by the use of a multiplier
whose inputs are the voltage regulator command signal, Va, and the exciter output voltage, Efd, times KR. This model is applicable to excitation systems employing static voltage regulators.
Reference: IEEE Standard 421.5-2005 Section 6.3.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 45.62.
ta
Voltage regulator time constant (TA). Typical Value = 0.013.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 1.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -0.95.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.17.
vemin
Minimum exciter voltage output (VEMIN). Typical Value = 0.1.
kr
Constant associated with regulator and alternator field power supply (KR). Typical Value = 3.77.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.143.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
kn
Excitation control system stabilizer gain (KN). Typical Value = 0.05.
efdn
Value of EFD at which feedback gain changes (EFDN). Typical Value = 2.36.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.104.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 0.499.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
vfemax
Exciter field current limit reference (VFEMAX). Typical Value = 16.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1) equals VEMAX (VE1). Typical Value = 6.24.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 1.143.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 4.68.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.1.
ExcIEEEAC4A
The class represents IEEE Std 421.5-2005 type AC4A model. The model represents type AC4A alternator-supplied controlled-rectifier excitation system which is quite different from the other type ac systems. This high initial response excitation system utilizes a full thyristor bridge in the exciter output circuit. The voltage regulator controls the firing of the thyristor bridges. The exciter alternator uses an independent voltage regulator to control its output voltage to a constant value. These effects are not modeled; however, transient loading effects on the exciter alternator are included.
Reference: IEEE Standard 421.5-2005 Section 6.4.
vimax
Maximum voltage regulator input limit (VIMAX). Typical Value = 10.
vimin
Minimum voltage regulator input limit (VIMIN). Typical Value = -10.
tc
Voltage regulator time constant (TC). Typical Value = 1.
tb
Voltage regulator time constant (TB). Typical Value = 10.
ka
Voltage regulator gain (KA). Typical Value = 200.
ta
Voltage regulator time constant (TA). Typical Value = 0.015.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 5.64.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -4.53.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.
ExcIEEEAC5A
The class represents IEEE Std 421.5-2005 type AC5A model. The model represents a simplified model for brushless excitation systems. The regulator is supplied from a source, such as a permanent magnet generator, which is not affected by system disturbances. Unlike other ac models, this model uses loaded rather than open circuit exciter saturation data in the same way as it is used for the dc models. Because the model has been widely implemented by the industry, it is sometimes used to represent other types of systems when either detailed data for them are not available or simplified models are required.
Reference: IEEE Standard 421.5-2005 Section 6.5.
ka
Voltage regulator gain (KA). Typical Value = 400.
ta
Voltage regulator time constant (TA). Typical Value = 0.02.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 7.3.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -7.3.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.8.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.03.
tf1
Excitation control system stabilizer time constant (TF1). Typical Value = 1.
tf2
Excitation control system stabilizer time constant (TF2). Typical Value = 1.
tf3
Excitation control system stabilizer time constant (TF3). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 5.6.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.86.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 4.2.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.5.
ExcIEEEAC6A
The class represents IEEE Std 421.5-2005 type AC6A model. The model represents field-controlled alternator-rectifier excitation systems with system-supplied electronic voltage regulators. The maximum output of the regulator, VR, is a function of terminal voltage, VT. The field current limiter included in the original model AC6A remains in the 2005 update.
Reference: IEEE Standard 421.5-2005 Section 6.6.
ka
Voltage regulator gain (KA). Typical Value = 536.
ta
Voltage regulator time constant (TA). Typical Value = 0.086.
tk
Voltage regulator time constant (TK). Typical Value = 0.18.
tb
Voltage regulator time constant (TB). Typical Value = 9.
tc
Voltage regulator time constant (TC). Typical Value = 3.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 75.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -75.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 44.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -36.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.
kh
Exciter field current limiter gain (KH). Typical Value = 92.
tj
Exciter field current limiter time constant (TJ). Typical Value = 0.02.
th
Exciter field current limiter time constant (TH). Typical Value = 0.08.
vfelim
Exciter field current limit reference (VFELIM). Typical Value = 19.
vhmax
Maximum field current limiter signal reference (VHMAX). Typical Value = 75.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.173.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 1.91.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.6.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1) equals VEMAX (VE1). Typical Value = 7.4.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.214.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 5.55.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.044.
ExcIEEEAC7B
The class represents IEEE Std 421.5-2005 type AC7B model. The model represents excitation systems which consist of an ac alternator with either stationary or rotating rectifiers to produce the dc field requirements. It is an upgrade to earlier ac excitation systems, which replace only the controls but retain the ac alternator and diode rectifier bridge.
Reference: IEEE Standard 421.5-2005 Section 6.7.
Note: In the IEEE Standard 421.5 – 2005, the [1 / sTE] block is shown as [1 / (1 + sTE)], which is incorrect.
kpr
Voltage regulator proportional gain (KPR). Typical Value = 4.24.
kir
Voltage regulator integral gain (KIR). Typical Value = 4.24.
kdr
Voltage regulator derivative gain (KDR). Typical Value = 0.
tdr
Lag time constant (TDR). Typical Value = 0.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 5.79.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -5.79.
kpa
Voltage regulator proportional gain (KPA). Typical Value = 65.36.
kia
Voltage regulator integral gain (KIA). Typical Value = 59.69.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 1.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -0.95.
kp
Potential circuit gain coefficient (KP). Typical Value = 4.96.
kl
Exciter field voltage lower limit parameter (KL). Typical Value = 10.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.1.
vfemax
Exciter field current limit reference (VFEMAX). Typical Value = 6.9.
vemin
Minimum exciter voltage output (VEMIN). Typical Value = 0.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.18.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 0.02.
kf1
Excitation control system stabilizer gain (KF1). Typical Value = 0.212.
kf2
Excitation control system stabilizer gain (KF2). Typical Value = 0.
kf3
Excitation control system stabilizer gain (KF3). Typical Value = 0.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1) equals VEMAX (VE1). Typical Value = 6.3.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.44.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 3.02.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 0.075.
ExcIEEEAC8B
The class represents IEEE Std 421.5-2005 type AC8B model. This model represents a PID voltage regulator with either a brushless exciter or dc exciter. The AVR in this model consists of PID control, with separate constants for the proportional (KPR), integral (KIR), and derivative (KDR) gains. The representation of the brushless exciter (TE, KE, SE, KC, KD) is similar to the model Type AC2A. The Type AC8B model can be used to represent static voltage regulators applied to brushless excitation systems. Digitally based voltage regulators feeding dc rotating main exciters can be represented with the AC Type AC8B model with the parameters KC and KD set to 0. For thyristor power stages fed from the generator terminals, the limits VRMAX and VRMIN should be a function of terminal voltage: VT * VRMAX and VT * VRMIN.
Reference: IEEE Standard 421.5-2005 Section 6.8.
kpr
Voltage regulator proportional gain (KPR). Typical Value = 80.
kir
Voltage regulator integral gain (KIR). Typical Value = 5.
kdr
Voltage regulator derivative gain (KDR). Typical Value = 10.
tdr
Lag time constant (TDR). Typical Value = 0.1.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 35.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 1.
ta
Voltage regulator time constant (TA). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.2.
vfemax
Exciter field current limit reference (VFEMAX). Typical Value = 6.
vemin
Minimum exciter voltage output (VEMIN). Typical Value = 0.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.55.
kd
Demagnetizing factor, a function of exciter alternator reactances (KD). Typical Value = 1.1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE1) equals VEMAX (VE1). Typical Value = 6.5.
seve1
Exciter saturation function value at the corresponding exciter voltage, VE1, back of commutating reactance (SE[VE1]). Typical Value = 0.3.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (VE2). Typical Value = 9.
seve2
Exciter saturation function value at the corresponding exciter voltage, VE2, back of commutating reactance (SE[VE2]). Typical Value = 3.
ExcIEEEDC1A
The class represents IEEE Std 421.5-2005 type DC1A model. This model represents field-controlled dc commutator exciters with continuously acting voltage regulators (especially the direct-acting rheostatic, rotating amplifier, and magnetic amplifier types). Because this model has been widely implemented by the industry, it is sometimes used to represent other types of systems when detailed data for them are not available or when a simplified model is required.
Reference: IEEE Standard 421.5-2005 Section 5.1.
ka
Voltage regulator gain (KA). Typical Value = 46.
ta
Voltage regulator time constant (TA). Typical Value = 0.06.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 1.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -0.9.
ke
Exciter constant related to self-excited field (KE). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.46.
kf
Excitation control system stabilizer gain (KF). Typical Value = 0.1.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 3.1.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.33.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 2.3.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.1.
uelin
UEL input (uelin).
true = input is connected to the HV gate
false = input connects to the error signal.
Typical Value = true.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero is not applied to integrator output.
Typical Value = true.
ExcIEEEDC2A
The class represents IEEE Std 421.5-2005 type DC2A model. This model represents represent field-controlled dc commutator exciters with continuously acting voltage regulators having supplies obtained from the generator or auxiliary bus. It differs from the Type DC1A model only in the voltage regulator output limits, which are now proportional to terminal voltage VT.
It is representative of solid-state replacements for various forms of older mechanical and rotating amplifier regulating equipment connected to dc commutator exciters.
Reference: IEEE Standard 421.5-2005 Section 5.2.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 3.05.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 2.29.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output. Typical Value = - 999 which means that there is no limit applied.
ka
Voltage regulator gain (KA). Typical Value = 300.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
kf
Excitation control system stabilizer gain (KF). Typical Value = 0.1.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.279.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.117.
ta
Voltage regulator time constant (TA). Typical Value = 0.01.
tb
Voltage regulator time constant (TB). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 1.33.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 0.675.
uelin
UEL input (uelin).
true = input is connected to the HV gate
false = input connects to the error signal.
Typical Value = true.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 4.95.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -4.9.
ExcIEEEDC3A
The class represents IEEE Std 421.5-2005 type DC3A model. This model represents represent older systems, in particular those dc commutator exciters with non-continuously acting regulators that were commonly used before the development of the continuously acting varieties. These systems respond at basically two different rates, depending upon the magnitude of voltage error. For small errors, adjustment is made periodically with a signal to a motor-operated rheostat. Larger errors cause resistors to be quickly shorted or inserted and a strong forcing signal applied to the exciter. Continuous motion of the motor-operated rheostat occurs for these larger error signals, even though it is bypassed by contactor action.
Reference: IEEE Standard 421.5-2005 Section 5.3.
trh
Rheostat travel time (TRH). Typical Value = 20.
kv
Fast raise/lower contact setting (KV). Typical Value = 0.05.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 1.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.5.
ke
Exciter constant related to self-excited field (KE). Typical Value = 0.05.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 3.375.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.267.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 3.15.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.068.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero is not applied to integrator output.
Typical Value = true.
ExcIEEEDC4B
The class represents IEEE Std 421.5-2005 type DC4B model. These excitation systems utilize a field-controlled dc commutator exciter with a continuously acting voltage regulator having supplies obtained from the generator or auxiliary bus.
Reference: IEEE Standard 421.5-2005 Section 5.4.
ka
Voltage regulator gain (KA). Typical Value = 1.
ta
Voltage regulator time constant (TA). Typical Value = 0.2.
kp
Regulator proportional gain (KP). Typical Value = 20.
ki
Regulator integral gain (KI). Typical Value = 20.
kd
Regulator derivative gain (KD). Typical Value = 20.
td
Regulator derivative filter time constant(TD). Typical Value = 0.01.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 2.7.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -0.9.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.8.
kf
Excitation control system stabilizer gain (KF). Typical Value = 0.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (EFD1). Typical Value = 1.75.
seefd1
Exciter saturation function value at the corresponding exciter voltage, EFD1 (SE[EFD1]). Typical Value = 0.08.
efd2
Exciter voltage at which exciter saturation is defined (EFD2). Typical Value = 2.33.
seefd2
Exciter saturation function value at the corresponding exciter voltage, EFD2 (SE[EFD2]). Typical Value = 0.27.
vemin
Minimum exciter voltage output(VEMIN). Typical Value = 0.
oelin
OEL input (OELin).
true = LV gate
false = subtract from error signal.
Typical Value = true.
uelin
UEL input (UELin).
true = HV gate
false = add to error signal.
Typical Value = true.
ExcIEEEST1A
The class represents IEEE Std 421.5-2005 type ST1A model. This model represents systems in which excitation power is supplied through a transformer from the generator terminals (or the unit’s auxiliary bus) and is regulated by a controlled rectifier. The maximum exciter voltage available from such systems is directly related to the generator terminal voltage.
Reference: IEEE Standard 421.5-2005 Section 7.1.
ilr
Exciter output current limit reference (ILR). Typical Value = 0.
ka
Voltage regulator gain (KA). Typical Value = 190.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.08.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.
klr
Exciter output current limiter gain (KLR). Typical Value = 0.
pssin
Selector of the Power System Stabilizer (PSS) input (PSSin).
true = PSS input (Vs) added to error signal
false = PSS input (Vs) added to voltage regulator output.
Typical Value = true.
ta
Voltage regulator time constant (TA). Typical Value = 0.
tb
Voltage regulator time constant (TB). Typical Value = 10.
tb1
Voltage regulator time constant (TB1). Typical Value = 0.
tc
Voltage regulator time constant (TC). Typical Value = 1.
tc1
Voltage regulator time constant (TC1). Typical Value = 0.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
uelin
Selector of the connection of the UEL input (UELin). Typical Value = ignoreUELsignal.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 14.5.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -14.5.
vimax
Maximum voltage regulator input limit (VIMAX). Typical Value = 999.
vimin
Minimum voltage regulator input limit (VIMIN). Typical Value = -999.
vrmax
Maximum voltage regulator outputs (VRMAX). Typical Value = 7.8.
vrmin
Minimum voltage regulator outputs (VRMIN). Typical Value = -6.7.
ExcIEEEST2A
The class represents IEEE Std 421.5-2005 type ST2A model. Some static systems utilize both current and voltage sources (generator terminal quantities) to comprise the power source. The regulator controls the exciter output through controlled saturation of the power transformer components. These compound-source rectifier excitation systems are designated Type ST2A and are represented by ExcIEEEST2A.
Reference: IEEE Standard 421.5-2005 Section 7.2.
ka
Voltage regulator gain (KA). Typical Value = 120.
ta
Voltage regulator time constant (TA). Typical Value = 0.15.
vrmax
Maximum voltage regulator outputs (VRMAX). Typical Value = 1.
vrmin
Minimum voltage regulator outputs (VRMIN). Typical Value = 0.
ke
Exciter constant related to self-excited field (KE). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (TE). Typical Value = 0.5.
kf
Excitation control system stabilizer gains (KF). Typical Value = 0.05.
tf
Excitation control system stabilizer time constant (TF). Typical Value = 1.
kp
Potential circuit gain coefficient (KP). Typical Value = 4.88.
ki
Potential circuit gain coefficient (KI). Typical Value = 8.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 1.82.
efdmax
Maximum field voltage (EFDMax). Typical Value = 99.
uelin
UEL input (UELin).
true = HV gate
false = add to error signal.
Typical Value = true.
ExcIEEEST3A
The class represents IEEE Std 421.5-2005 type ST3A model. Some static systems utilize a field voltage control loop to linearize the exciter control characteristic. This also makes the output independent of supply source variations until supply limitations are reached. These systems utilize a variety of controlled-rectifier designs: full thyristor complements or hybrid bridges
in either series or shunt configurations. The power source may consist of only a potential source, either fed from the machine terminals or from internal windings. Some designs may have compound power sources utilizing both machine potential and current. These power sources are represented as phasor combinations of machine terminal current and voltage and are accommodated by suitable parameters in model Type ST3A which is represented by ExcIEEEST3A.
Reference: IEEE Standard 421.5-2005 Section 7.3.
vimax
Maximum voltage regulator input limit (VIMAX). Typical Value = 0.2.
vimin
Minimum voltage regulator input limit (VIMIN). Typical Value = -0.2.
ka
Voltage regulator gain (KA). This is parameter K in the IEEE Std. Typical Value = 200.
ta
Voltage regulator time constant (TA). Typical Value = 0.
tb
Voltage regulator time constant (TB). Typical Value = 10.
tc
Voltage regulator time constant (TC). Typical Value = 1.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 10.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -10.
km
Forward gain constant of the inner loop field regulator (KM). Typical Value = 7.93.
tm
Forward time constant of inner loop field regulator (TM). Typical Value = 0.4.
vmmax
Maximum inner loop output (VMMax). Typical Value = 1.
vmmin
Minimum inner loop output (VMMin). Typical Value = 0.
kg
Feedback gain constant of the inner loop field regulator (KG). Typical Value = 1.
kp
Potential circuit gain coefficient (KP). Typical Value = 6.15.
thetap
Potential circuit phase angle (thetap). Typical Value = 0.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
multiplier
ki
Potential circuit gain coefficient (KI). Typical Value = 0.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.2.
xl
Reactance associated with potential source (XL). Typical Value = 0.081.
vbmax
Maximum excitation voltage (VBMax). Typical Value = 6.9.
vgmax
Maximum inner loop feedback voltage (VGMax). Typical Value = 5.8.
ExcIEEEST4B
The class represents IEEE Std 421.5-2005 type ST4B model. This model is a variation of the Type ST3A model, with a proportional plus integral (PI) regulator block replacing the lag-lead regulator characteristic that is in the ST3A model. Both potential and compound source rectifier excitation systems are modeled. The PI regulator blocks have non-windup limits that are represented. The voltage regulator of this model is typically implemented digitally.
Reference: IEEE Standard 421.5-2005 Section 7.4.
kpr
Voltage regulator proportional gain (KPR). Typical Value = 10.75.
kir
Voltage regulator integral gain (KIR). Typical Value = 10.75.
ta
Voltage regulator time constant (TA). Typical Value = 0.02.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 1.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -0.87.
kpm
Voltage regulator proportional gain output (KPM). Typical Value = 1.
kim
Voltage regulator integral gain output (KIM). Typical Value = 0.
vmmax
Maximum inner loop output (VMMax). Typical Value = 99.
vmmin
Minimum inner loop output (VMMin). Typical Value = -99.
kg
Feedback gain constant of the inner loop field regulator (KG). Typical Value = 0.
kp
Potential circuit gain coefficient (KP). Typical Value = 9.3.
thetap
Potential circuit phase angle (thetap). Typical Value = 0.
ki
Potential circuit gain coefficient (KI). Typical Value = 0.
kc
Rectifier loading factor proportional to commutating reactance (KC). Typical Value = 0.113.
xl
Reactance associated with potential source (XL). Typical Value = 0.124.
vbmax
Maximum excitation voltage (VBMax). Typical Value = 11.63.
ExcIEEEST5B
The class represents IEEE Std 421.5-2005 type ST5B model. The Type ST5B excitation system is a variation of the Type ST1A model, with alternative overexcitation and underexcitation inputs and additional limits.
Reference: IEEE Standard 421.5-2005 Section 7.5.
Note: the block diagram in the IEEE 421.5 standard has input signal Vc and does not indicate the summation point with Vref. The implementation of the ExcIEEEST5B shall consider summation point with Vref.
kr
Regulator gain (KR). Typical Value = 200.
t1
Firing circuit time constant (T1). Typical Value = 0.004.
kc
Rectifier regulation factor (KC). Typical Value = 0.004.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 5.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -4.
tc1
Regulator lead time constant (TC1). Typical Value = 0.8.
tb1
Regulator lag time constant (TB1). Typical Value = 6.
tc2
Regulator lead time constant (TC2). Typical Value = 0.08.
tb2
Regulator lag time constant (TB2). Typical Value = 0.01.
toc1
OEL lead time constant (TOC1). Typical Value = 0.1.
tob1
OEL lag time constant (TOB1). Typical Value = 2.
toc2
OEL lead time constant (TOC2). Typical Value = 0.08.
tob2
OEL lag time constant (TOB2). Typical Value = 0.08.
tuc1
UEL lead time constant (TUC1). Typical Value = 2.
tub1
UEL lag time constant (TUB1). Typical Value = 10.
tuc2
UEL lead time constant (TUC2). Typical Value = 0.1.
tub2
UEL lag time constant (TUB2). Typical Value = 0.05.
ExcIEEEST6B
The class represents IEEE Std 421.5-2005 type ST6B model. This model consists of a PI voltage regulator with an inner loop field voltage regulator and pre-control. The field voltage regulator implements a proportional control. The pre-control and the delay in the feedback circuit increase the dynamic response.
Reference: IEEE Standard 421.5-2005 Section 7.6.
ilr
Exciter output current limit reference (ILR). Typical Value = 4.164.
kci
Exciter output current limit adjustment (KCI). Typical Value = 1.0577.
kff
Pre-control gain constant of the inner loop field regulator (KFF). Typical Value = 1.
kg
Feedback gain constant of the inner loop field regulator (KG). Typical Value = 1.
kia
Voltage regulator integral gain (KIA). Typical Value = 45.094.
klr
Exciter output current limiter gain (KLR). Typical Value = 17.33.
km
Forward gain constant of the inner loop field regulator (KM). Typical Value = 1.
kpa
Voltage regulator proportional gain (KPA). Typical Value = 18.038.
oelin
OEL input selector (OELin). Typical Value = noOELinput.
tg
Feedback time constant of inner loop field voltage regulator (TG). Typical Value = 0.02.
vamax
Maximum voltage regulator output (VAMAX). Typical Value = 4.81.
vamin
Minimum voltage regulator output (VAMIN). Typical Value = -3.85.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 4.81.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -3.85.
ExcIEEEST7B
The class represents IEEE Std 421.5-2005 type ST7B model. This model is representative of static potential-source excitation systems. In this system, the AVR consists of a PI voltage regulator. A phase lead-lag filter in series allows introduction of a derivative function, typically used with brushless excitation systems. In that case, the regulator is of the PID type. In addition, the terminal voltage channel includes a phase lead-lag filter. The AVR includes the appropriate inputs on its reference for overexcitation limiter (OEL1), underexcitation limiter (UEL), stator current limiter (SCL), and current compensator (DROOP). All these limitations, when they work at voltage reference level, keep the PSS (VS signal from Type PSS1A, PSS2A, or PSS2B) in operation. However, the UEL limitation can also be transferred to the high value (HV) gate acting on the output signal. In addition, the output signal passes through a low value (LV) gate for a ceiling overexcitation limiter (OEL2).
Reference: IEEE Standard 421.5-2005 Section 7.7.
kh
High-value gate feedback gain (KH). Typical Value 1.
kia
Voltage regulator integral gain (KIA). Typical Value = 1.
kl
Low-value gate feedback gain (KL). Typical Value 1.
kpa
Voltage regulator proportional gain (KPA). Typical Value = 40.
oelin
OEL input selector (OELin). Typical Value = noOELinput.
tb
Regulator lag time constant (TB). Typical Value 1.
tc
Regulator lead time constant (TC). Typical Value 1.
tf
Excitation control system stabilizer time constant (TF). Typical Value 1.
tg
Feedback time constant of inner loop field voltage regulator (TG). Typical Value 1.
tia
Feedback time constant (TIA). Typical Value = 3.
uelin
UEL input selector (UELin). Typical Value = noUELinput.
vmax
Maximum voltage reference signal (VMAX). Typical Value = 1.1.
vmin
Minimum voltage reference signal (VMIN). Typical Value = 0.9.
vrmax
Maximum voltage regulator output (VRMAX). Typical Value = 5.
vrmin
Minimum voltage regulator output (VRMIN). Typical Value = -4.5.
ExcAC1A
Modified IEEE AC1A alternator-supplied rectifier excitation system with different rate feedback source.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ka
Voltage regulator gain (Ka). Typical Value = 400.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 14.5.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -14.5.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.8.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.03.
kf1
Coefficient to allow different usage of the model (Kf1). Typical Value = 0.
kf2
Coefficient to allow different usage of the model (Kf2). Typical Value = 1.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.2.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 0.38.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1). Typical Value = 4.18.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.1.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 3.14.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 0.03.
vrmax
Maximum voltage regulator outputs (Vrmax). Typical Value = 6.03.
vrmin
Minimum voltage regulator outputs (Rrmin). Typical Value = -5.43.
hvlvgates
Indicates if both HV gate and LV gate are active (HVLVgates).
true = gates are used
false = gates are not used.
Typical Value = true.
ExcAC2A
Modified IEEE AC2A alternator-supplied rectifier excitation system with different field current limit.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ka
Voltage regulator gain (Ka). Typical Value = 400.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 8.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -8.
kb
Second stage regulator gain (Kb) (>0). Exciter field current controller gain. Typical Value = 25.
kb1
Second stage regulator gain (Kb1). It is exciter field current controller gain used as alternative to Kb to represent a variant of the ExcAC2A model. Typical Value = 25.
vrmax
Maximum voltage regulator outputs (Vrmax). Typical Value = 105.
vrmin
Minimum voltage regulator outputs (Vrmin). Typical Value = -95.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.6.
vfemax
Exciter field current limit reference (Vfemax). Typical Value = 4.4.
kh
Exciter field current feedback gain (Kh). Typical Value = 1.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.03.
kl
Exciter field current limiter gain (Kl). Typical Value = 10.
vlr
Maximum exciter field current (Vlr). Typical Value = 4.4.
kl1
Coefficient to allow different usage of the model (Kl1). Typical Value = 1.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.28.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 0.35.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1). Typical Value = 4.4.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.037.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 3.3.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 0.012.
hvgate
Indicates if HV gate is active (HVgate).
true = gate is used
false = gate is not used.
Typical Value = true.
lvgate
Indicates if LV gate is active (LVgate).
true = gate is used
false = gate is not used.
Typical Value = true.
ExcAC3A
Modified IEEE AC3A alternator-supplied rectifier excitation system with different field current limit.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ka
Voltage regulator gain (Ka). Typical Value = 45.62.
ta
Voltage regulator time constant (Ta). Typical Value = 0.013.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 1.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -0.95.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.17.
vemin
Minimum exciter voltage output (Vemin). Typical Value = 0.1.
kr
Constant associated with regulator and alternator field power supply (Kr). Typical Value =3.77.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.143.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
kn
Excitation control system stabilizer gain (Kn). Typical Value =0.05.
efdn
Value of EFD at which feedback gain changes (Efdn). Typical Value = 2.36.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.104.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 0.499.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
klv
Gain used in the minimum field voltage limiter loop (Klv). Typical Value = 0.194.
kf1
Coefficient to allow different usage of the model (Kf1). Typical Value = 1.
kf2
Coefficient to allow different usage of the model (Kf2). Typical Value = 0.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
vfemax
Exciter field current limit reference (Vfemax). Typical Value = 16.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1) equals Vemax (Ve1). Typical Value = 6.24.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 1.143.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 4.68.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 0.1.
vlv
Field voltage used in the minimum field voltage limiter loop (Vlv). Typical Value = 0.79.
ExcAC4A
Modified IEEE AC4A alternator-supplied rectifier excitation system with different minimum controller output.
vimax
Maximum voltage regulator input limit (Vimax). Typical Value = 10.
vimin
Minimum voltage regulator input limit (Vimin). Typical Value = -10.
tc
Voltage regulator time constant (Tc). Typical Value = 1.
tb
Voltage regulator time constant (Tb). Typical Value = 10.
ka
Voltage regulator gain (Ka). Typical Value = 200.
ta
Voltage regulator time constant (Ta). Typical Value = 0.015.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 5.64.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -4.53.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.
ExcAC5A
Modified IEEE AC5A alternator-supplied rectifier excitation system with different minimum controller output.
ka
Voltage regulator gain (Ka). Typical Value = 400.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 7.3.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value =-7.3.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.8.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.03.
tf1
Excitation control system stabilizer time constant (Tf1). Typical Value = 1.
tf2
Excitation control system stabilizer time constant (Tf2). Typical Value = 0.8.
tf3
Excitation control system stabilizer time constant (Tf3). Typical Value = 0.
efd1
Exciter voltage at which exciter saturation is defined (Efd1). Typical Value = 5.6.
seefd1
Exciter saturation function value at the corresponding exciter voltage, Efd1 (SE[Efd1]). Typical Value = 0.86.
efd2
Exciter voltage at which exciter saturation is defined (Efd2). Typical Value = 4.2.
seefd2
Exciter saturation function value at the corresponding exciter voltage, Efd2 (SE[Efd2]). Typical Value = 0.5.
a
Coefficient to allow different usage of the model (a). Typical Value = 1.
ExcAC6A
Modified IEEE AC6A alternator-supplied rectifier excitation system with speed input.
ka
Voltage regulator gain (Ka). Typical Value = 536.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
ta
Voltage regulator time constant (Ta). Typical Value = 0.086.
tk
Voltage regulator time constant (Tk). Typical Value = 0.18.
tb
Voltage regulator time constant (Tb). Typical Value = 9.
tc
Voltage regulator time constant (Tc). Typical Value = 3.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 75.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -75.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 44.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -36.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.
kh
Exciter field current limiter gain (Kh). Typical Value = 92.
tj
Exciter field current limiter time constant (Tj). Typical Value = 0.02.
th
Exciter field current limiter time constant (Th). Typical Value = 0.08.
vfelim
Exciter field current limit reference (Vfelim). Typical Value = 19.
vhmax
Maximum field current limiter signal reference (Vhmax). Typical Value = 75.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.173.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 1.91.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.6.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1). Typical Value = 7.4.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.214.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 5.55.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 0.044.
ExcAC8B
Modified IEEE AC8B alternator-supplied rectifier excitation system with speed input and input limiter.
inlim
Input limiter indicator.
true = input limiter Vimax and Vimin is considered
false = input limiter Vimax and Vimin is not considered.
Typical Value = true.
ka
Voltage regulator gain (Ka). Typical Value = 1.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.55.
kd
Demagnetizing factor, a function of exciter alternator reactances (Kd). Typical Value = 1.1.
kdr
Voltage regulator derivative gain (Kdr). Typical Value = 10.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
kir
Voltage regulator integral gain (Kir). Typical Value = 5.
kpr
Voltage regulator proportional gain (Kpr). Typical Value = 80.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
pidlim
PID limiter indicator.
true = input limiter Vpidmax and Vpidmin is considered
false = input limiter Vpidmax and Vpidmin is not considered.
Typical Value = true.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.3.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 3.
ta
Voltage regulator time constant (Ta). Typical Value = 0.
tdr
Lag time constant (Tdr). Typical Value = 0.1.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.2.
telim
Selector for the limiter on the block [1/sTe].
See diagram for meaning of true and false.
Typical Value = false.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1) equals VEMAX (Ve1). Typical Value = 6.5.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 9.
vemin
Minimum exciter voltage output (Vemin). Typical Value = 0.
vfemax
Exciter field current limit reference (Vfemax). Typical Value = 6.
vimax
Input signal maximum (Vimax). Typical Value = 35.
vimin
Input signal minimum (Vimin). Typical Value = -10.
vpidmax
PID maximum controller output (Vpidmax). Typical Value = 35.
vpidmin
PID minimum controller output (Vpidmin). Typical Value = -10.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 35.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = 0.
vtmult
Multiply by generator's terminal voltage indicator.
true =the limits Vrmax and Vrmin are multiplied by the generator’s terminal voltage to represent a thyristor power stage fed from the generator terminals
false = limits are not multiplied by generator's terminal voltage.
Typical Value = false.
ExcANS
Italian excitation system. It represents static field voltage or excitation current feedback excitation system.
k3
AVR gain (K3). Typical Value = 1000.
k2
Exciter gain (K2). Typical Value = 20.
kce
Ceiling factor (KCE). Typical Value = 1.
t3
Time constant (T3). Typical Value = 1.6.
t2
Time constant (T2). Typical Value = 0.05.
t1
Time constant (T1). Typical Value = 20.
blint
Governor Control Flag (BLINT).
0 = lead-lag regulator
1 = proportional integral regulator.
Typical Value = 0.
kvfif
Rate feedback signal flag (KVFIF).
0 = output voltage of the exciter
1 = exciter field current.
Typical Value = 0.
ifmn
Minimum exciter current (IFMN). Typical Value = -5.2.
ifmx
Maximum exciter current (IFMX). Typical Value = 6.5.
vrmn
Maximum AVR output (VRMN). Typical Value = -5.2.
vrmx
Minimum AVR output (VRMX). Typical Value = 6.5.
krvecc
Feedback enabling (KRVECC).
0 = Open loop control
1 = Closed loop control.
Typical Value = 1.
tb
Exciter time constant (TB). Typical Value = 0.04.
ExcAVR1
Italian excitation system corresponding to IEEE (1968) Type 1 Model. It represents exciter dynamo and electromechanical regulator.
ka
AVR gain (KA). Typical Value = 500.
vrmn
Maximum AVR output (VRMN). Typical Value = -6.
vrmx
Minimum AVR output (VRMX). Typical Value = 7.
ta
AVR time constant (TA). Typical Value = 0.2.
tb
AVR time constant (TB). Typical Value = 0.
te
Exciter time constant (TE). Typical Value = 1.
e1
Field voltage value 1 (E1). Typical Value = 4.18.
se1
Saturation factor at E1 (S(E1)). Typical Value = 0.1.
e2
Field voltage value 2 (E2). Typical Value = 3.14.
se2
Saturation factor at E2 (S(E2)). Typical Value = 0.03.
kf
Rate feedback gain (KF). Typical Value = 0.02.
tf
Rate feedback time constant (TF). Typical Value = 1.
ExcAVR2
Italian excitation system corresponding to IEEE (1968) Type 2 Model. It represents alternator and rotating diodes and electromechanic voltage regulators.
ka
AVR gain (KA). Typical Value = 500.
vrmn
Maximum AVR output (VRMN). Typical Value = -6.
vrmx
Minimum AVR output (VRMX). Typical Value = 7.
ta
AVR time constant (TA). Typical Value = 0.02.
tb
AVR time constant (TB). Typical Value = 0.
te
Exciter time constant (TE). Typical Value = 1.
e1
Field voltage value 1 (E1). Typical Value = 4.18.
se1
Saturation factor at E1 (S(E1)). Typical Value = 0.1.
e2
Field voltage value 2 (E2). Typical Value = 3.14.
se2
Saturation factor at E2 (S(E2)). Typical Value = 0.03.
kf
Rate feedback gain (KF). Typical Value = 0.02.
tf1
Rate feedback time constant (TF1). Typical Value = 1.
tf2
Rate feedback time constant (TF2). Typical Value = 1.
ExcAVR3
Italian excitation system. It represents exciter dynamo and electric regulator.
ka
AVR gain (KA). Typical Value = 3000.
vrmn
Maximum AVR output (VRMN). Typical Value = -7.5.
vrmx
Minimum AVR output (VRMX). Typical Value = 7.5.
t1
AVR time constant (T1). Typical Value = 220.
t2
AVR time constant (T2). Typical Value = 1.6.
t3
AVR time constant (T3). Typical Value = 0.66.
t4
AVR time constant (T4). Typical Value = 0.07.
te
Exciter time constant (TE). Typical Value = 1.
e1
Field voltage value 1 (E1). Typical Value = 4.18.
se1
Saturation factor at E1 (S(E1)). Typical Value = 0.1.
e2
Field voltage value 2 (E2). Typical Value = 3.14.
se2
Saturation factor at E2 (S(E2)). Typical Value = 0.03.
ExcAVR4
Italian excitation system. It represents static exciter and electric voltage regulator.
ka
AVR gain (KA). Typical Value = 300.
vrmn
Maximum AVR output (VRMN). Typical Value = 0.
vrmx
Minimum AVR output (VRMX). Typical Value = 5.
t1
AVR time constant (T1). Typical Value = 4.8.
t2
AVR time constant (T2). Typical Value = 1.5.
t3
AVR time constant (T3). Typical Value = 0.
t4
AVR time constant (T4). Typical Value = 0.
ke
Exciter gain (KE). Typical Value = 1.
vfmx
Maximum exciter output (VFMX). Typical Value = 5.
vfmn
Minimum exciter output (VFMN). Typical Value = 0.
kif
Exciter internal reactance (KIF). Typical Value = 0.
tif
Exciter current feedback time constant (TIF). Typical Value = 0.
t1if
Exciter current feedback time constant (T1IF). Typical Value = 60.
imul
AVR output voltage dependency selector (Imul).
true = selector is connected
false = selector is not connected.
Typical Value = true.
ExcAVR5
Manual excitation control with field circuit resistance. This model can be used as a very simple representation of manual voltage control.
ka
Gain (Ka).
ta
Time constant (Ta).
rex
Effective Output Resistance (Rex). Rex represents the effective output resistance seen by the excitation system.
ExcAVR7
IVO excitation system.
k1
Gain (K1). Typical Value = 1.
a1
Lead coefficient (A1). Typical Value = 0.5.
a2
Lag coefficient (A2). Typical Value = 0.5.
t1
Lead time constant (T1). Typical Value = 0.05.
t2
Lag time constant (T2). Typical Value = 0.1.
vmax1
Lead-lag max. limit (Vmax1). Typical Value = 5.
vmin1
Lead-lag min. limit (Vmin1). Typical Value = -5.
k3
Gain (K3). Typical Value = 3.
a3
Lead coefficient (A3). Typical Value = 0.5.
a4
Lag coefficient (A4). Typical Value = 0.5.
t3
Lead time constant (T3). Typical Value = 0.1.
t4
Lag time constant (T4). Typical Value = 0.1.
vmax3
Lead-lag max. limit (Vmax3). Typical Value = 5.
vmin3
Lead-lag min. limit (Vmin3). Typical Value = -5.
k5
Gain (K5). Typical Value = 1.
a5
Lead coefficient (A5). Typical Value = 0.5.
a6
Lag coefficient (A6). Typical Value = 0.5.
t5
Lead time constant (T5). Typical Value = 0.1.
t6
Lag time constant (T6). Typical Value = 0.1.
vmax5
Lead-lag max. limit (Vmax5). Typical Value = 5.
vmin5
Lead-lag min. limit (Vmin5). Typical Value = -2.
ExcBBC
Transformer fed static excitation system (static with ABB regulator). This model represents a static excitation system in which a gated thyristor bridge fed by a transformer at the main generator terminals feeds the main generator directly.
t1
Controller time constant (T1). Typical Value = 6.
t2
Controller time constant (T2). Typical Value = 1.
t3
Lead/lag time constant (T3). Typical Value = 0.05.
t4
Lead/lag time constant (T4). Typical Value = 0.01.
k
Steady state gain (K). Typical Value = 300.
vrmin
Minimum control element output (Vrmin). Typical Value = -5.
vrmax
Maximum control element output (Vrmax). Typical Value = 5.
efdmin
Minimum open circuit exciter voltage (Efdmin). Typical Value = -5.
efdmax
Maximum open circuit exciter voltage (Efdmax). Typical Value = 5.
xe
Effective excitation transformer reactance (Xe). Typical Value = 0.05.
switch
Supplementary signal routing selector (switch).
true = Vs connected to 3rd summing point
false = Vs connected to 1st summing point (see diagram).
Typical Value = true.
ExcCZ
Czech Proportion/Integral Exciter.
kp
Regulator proportional gain (Kp).
tc
Regulator integral time constant (Tc).
vrmax
Voltage regulator maximum limit (Vrmax).
vrmin
Voltage regulator minimum limit (Vrmin).
ka
Regulator gain (Ka).
ta
Regulator time constant (Ta).
ke
Exciter constant related to self-excited field (Ke).
te
Exciter time constant, integration rate associated with exciter control (Te).
efdmax
Exciter output maximum limit (Efdmax).
efdmin
Exciter output minimum limit (Efdmin).
ExcDC1A
Modified IEEE DC1A direct current commutator exciter with speed input and without underexcitation limiters (UEL) inputs.
ka
Voltage regulator gain (Ka). Typical Value = 46.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
ta
Voltage regulator time constant (Ta). Typical Value = 0.06.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 1.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -0.9.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.46.
kf
Excitation control system stabilizer gain (Kf). Typical Value = 0.1.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (Efd1). Typical Value = 3.1.
seefd1
Exciter saturation function value at the corresponding exciter voltage, Efd1 (Se[Eefd1]). Typical Value = 0.33.
efd2
Exciter voltage at which exciter saturation is defined (Efd2). Typical Value = 2.3.
seefd2
Exciter saturation function value at the corresponding exciter voltage, Efd1 (Se[Eefd1]). Typical Value = 0.33.
exclim
(exclim).
IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero is not applied to integrator output.
Typical Value = true.
efdmin
Minimum voltage exciter output limiter (Efdmin). Typical Value = -99.
edfmax
Maximum voltage exciter output limiter (Efdmax). Typical Value = 99.
ExcDC2A
Modified IEEE DC2A direct current commutator exciters with speed input, one more leg block in feedback loop and without underexcitation limiters (UEL) inputs. DC type 2 excitation system model with added speed multiplier, added lead-lag, and voltage-dependent limits.
ka
Voltage regulator gain (Ka). Typical Value = 300.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
ta
Voltage regulator time constant (Ta). Typical Value = 0.01.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 4.95.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -4.9.
ke
Exciter constant related to self-excited field (Ke). If Ke is entered as zero, the model calculates an effective value of Ke such that the initial condition value of Vr is zero. The zero value of Ke is not changed. If Ke is entered as non-zero, its value is used directly, without change. Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.33.
kf
Excitation control system stabilizer gain (Kf). Typical Value = 0.1.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 0.675.
tf1
Excitation control system stabilizer time constant (Tf1). Typical Value = 0.
efd1
Exciter voltage at which exciter saturation is defined (Efd1). Typical Value = 3.05.
seefd1
Exciter saturation function value at the corresponding exciter voltage, Efd1 (Se[Eefd1]). Typical Value = 0.279.
efd2
Exciter voltage at which exciter saturation is defined (Efd2). Typical Value = 2.29.
seefd2
Exciter saturation function value at the corresponding exciter voltage, Efd2 (Se[Efd2]). Typical Value = 0.117.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero is not applied to integrator output.
Typical Value = true.
vtlim
(Vtlim).
true = limiter at the block [Ka/(1+sTa)] is dependent on Vt
false = limiter at the block is not dependent on Vt.
Typical Value = true.
ExcDC3A
This is modified IEEE DC3A direct current commutator exciters with speed input, and death band. DC old type 4.
trh
Rheostat travel time (Trh). Typical Value = 20.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
kr
Death band (Kr). If Kr is not zero, the voltage regulator input changes at a constant rate if Verr > Kr or Verr < -Kr as per the IEEE (1968) Type 4 model. If Kr is zero, the error signal drives the voltage regulator continuously as per the IEEE (1980) DC3 and IEEE (1992, 2005) DC3A models. Typical Value = 0.
kv
Fast raise/lower contact setting (Kv). Typical Value = 0.05.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 5.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.83.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
efd1
Exciter voltage at which exciter saturation is defined (Efd1). Typical Value = 2.6.
seefd1
Exciter saturation function value at the corresponding exciter voltage, Efd1 (Se[Eefd1]). Typical Value = 0.1.
efd2
Exciter voltage at which exciter saturation is defined (Efd2). Typical Value = 3.45.
seefd2
Exciter saturation function value at the corresponding exciter voltage, Efd2 (Se[Efd2]). Typical Value = 0.35.
exclim
(exclim). IEEE standard is ambiguous about lower limit on exciter output.
true = a lower limit of zero is applied to integrator output
false = a lower limit of zero not applied to integrator output.
Typical Value = true.
edfmax
Maximum voltage exciter output limiter (Efdmax). Typical Value = 99.
efdmin
Minimum voltage exciter output limiter (Efdmin). Typical Value = -99.
efdlim
(Efdlim).
true = exciter output limiter is active
false = exciter output limiter not active.
Typical Value = true.
ExcDC3A1
This is modified old IEEE type 3 excitation system.
ka
Voltage regulator gain (Ka). Typical Value = 300.
ta
Voltage regulator time constant (Ta). Typical Value = 0.01.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 5.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = 0.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 1.83.
kf
Excitation control system stabilizer gain (Kf). Typical Value = 0.1.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 0.675.
kp
Potential circuit gain coefficient (Kp). Typical Value = 4.37.
ki
Potential circuit gain coefficient (Ki). Typical Value = 4.83.
vbmax
Available exciter voltage limiter (Vbmax). Typical Value = 11.63.
exclim
(exclim).
true = lower limit of zero is applied to integrator output
false = lower limit of zero not applied to integrator output.
Typical Value = true.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
vb1max
Available exciter voltage limiter (Vb1max). Typical Value = 11.63.
vblim
Vb limiter indicator.
true = exciter Vbmax limiter is active
false = Vb1max is active.
Typical Value = true.
ExcELIN1
Static PI transformer fed excitation system: ELIN (VATECH) - simplified model. This model represents an all-static excitation system. A PI voltage controller establishes a desired field current set point for a proportional current controller. The integrator of the PI controller has a follow-up input to match its signal to the present field current. A power system stabilizer with power input is included in the model.
tfi
Current transducer time constant (Tfi). Typical Value = 0.
tnu
Controller reset time constant (Tnu). Typical Value = 2.
vpu
Voltage controller proportional gain (Vpu). Typical Value = 34.5.
vpi
Current controller gain (Vpi). Typical Value = 12.45.
vpnf
Controller follow up gain (Vpnf). Typical Value = 2.
dpnf
Controller follow up dead band (Dpnf). Typical Value = 0.
tsw
Stabilizer parameters (Tsw). Typical Value = 3.
efmin
Minimum open circuit excitation voltage (Efmin). Typical Value = -5.
efmax
Maximum open circuit excitation voltage (Efmax). Typical Value = 5.
xe
Excitation transformer effective reactance (Xe) (>=0). Xe represents the regulation of the transformer/rectifier unit. Typical Value = 0.06.
ks1
Stabilizer Gain 1 (Ks1). Typical Value = 0.
ks2
Stabilizer Gain 2 (Ks2). Typical Value = 0.
ts1
Stabilizer Phase Lag Time Constant (Ts1). Typical Value = 1.
ts2
Stabilizer Filter Time Constant (Ts2). Typical Value = 1.
smax
Stabilizer Limit Output (smax). Typical Value = 0.1.
ExcELIN2
Detailed Excitation System Model - ELIN (VATECH). This model represents an all-static excitation system. A PI voltage controller establishes a desired field current set point for a proportional current controller. The integrator of the PI controller has a follow-up input to match its signal to the present field current. Power system stabilizer models used in conjunction with this excitation system model: PssELIN2, PssIEEE2B, Pss2B.
k1
Voltage regulator input gain (K1). Typical Value = 0.
k1ec
Voltage regulator input limit (K1ec). Typical Value = 2.
kd1
Voltage controller derivative gain (Kd1). Typical Value = 34.5.
tb1
Voltage controller derivative washout time constant (Tb1). Typical Value = 12.45.
pid1max
Controller follow up gain (PID1max). Typical Value = 2.
ti1
Controller follow up dead band (Ti1). Typical Value = 0.
iefmax2
Minimum open circuit excitation voltage (Iefmax2). Typical Value = -5.
k2
Gain (K2). Typical Value = 5.
ketb
Gain (Ketb). Typical Value = 0.06.
upmax
Limiter (Upmax). Typical Value = 3.
upmin
Limiter (Upmin). Typical Value = 0.
te
Time constant (Te). Typical Value = 0.
xp
Excitation transformer effective reactance (Xp). Typical Value = 1.
te2
Time Constant (Te2). Typical Value = 1.
ke2
Gain (Ke2). Typical Value = 0.1.
ve1
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve1). Typical Value = 3.
seve1
Exciter saturation function value at the corresponding exciter voltage, Ve1, back of commutating reactance (Se[Ve1]). Typical Value = 0.
ve2
Exciter alternator output voltages back of commutating reactance at which saturation is defined (Ve2). Typical Value = 0.
seve2
Exciter saturation function value at the corresponding exciter voltage, Ve2, back of commutating reactance (Se[Ve2]). Typical Value = 1.
tr4
Time constant (Tr4). Typical Value = 1.
k3
Gain (K3). Typical Value = 0.1.
ti3
Time constant (Ti3). Typical Value = 3.
k4
Gain (K4). Typical Value = 0.
ti4
Time constant (Ti4). Typical Value = 0.
iefmax
Limiter (Iefmax). Typical Value = 1.
iefmin
Limiter (Iefmin). Typical Value = 1.
efdbas
Gain (Efdbas). Typical Value = 0.1.
ExcHU
Hungarian Excitation System Model, with built-in voltage transducer.
tr
Filter time constant (Tr). If a voltage compensator is used in conjunction with this excitation system model, Tr should be set to 0. Typical Value = 0.01.
te
Major loop PI tag integration time constant (Te). Typical Value = 0.154.
imin
Major loop PI tag output signal lower limit (Imin). Typical Value = 0.1.
imax
Major loop PI tag output signal upper limit (Imax). Typical Value = 2.19.
ae
Major loop PI tag gain factor (Ae). Typical Value = 3.
emin
Field voltage control signal lower limit on AVR base (Emin). Typical Value = -0.866.
emax
Field voltage control signal upper limit on AVR base (Emax). Typical Value = 0.996.
ki
Current base conversion constant (Ki). Typical Value = 0.21428.
ai
Minor loop PI tag gain factor (Ai). Typical Value = 22.
ti
Minor loop PI control tag integration time constant (Ti). Typical Value = 0.01333.
atr
AVR constant (Atr). Typical Value = 2.19.
ke
Voltage base conversion constant (Ke). Typical Value = 4.666.
ExcOEX3T
Modified IEEE Type ST1 Excitation System with semi-continuous and acting terminal voltage limiter.
t1
Time constant (T1).
t2
Time constant (T2).
t3
Time constant (T3).
t4
Time constant (T4).
ka
Gain (KA).
t5
Time constant (T5).
t6
Time constant (T6).
vrmax
Limiter (VRMAX).
vrmin
Limiter (VRMIN).
te
Time constant (TE).
kf
Gain (KF).
tf
Time constant (TF).
kc
Gain (KC).
kd
Gain (KD).
ke
Gain (KE).
e1
Saturation parameter (E1).
see1
Saturation parameter (SE(E1)).
e2
Saturation parameter (E2).
see2
Saturation parameter (SE(E2)).
ExcPIC
Proportional/Integral Regulator Excitation System Model. This model can be used to represent excitation systems with a proportional-integral (PI) voltage regulator controller.
ka
PI controller gain (Ka). Typical Value = 3.15.
ta1
PI controller time constant (Ta1). Typical Value = 1.
vr1
PI maximum limit (Vr1). Typical Value = 1.
vr2
PI minimum limit (Vr2). Typical Value = -0.87.
ta2
Voltage regulator time constant (Ta2). Typical Value = 0.01.
ta3
Lead time constant (Ta3). Typical Value = 0.
ta4
Lag time constant (Ta4). Typical Value = 0.
vrmax
Voltage regulator maximum limit (Vrmax). Typical Value = 1.
vrmin
Voltage regulator minimum limit (Vrmin). Typical Value = -0.87.
kf
Rate feedback gain (Kf). Typical Value = 0.
tf1
Rate feedback time constant (Tf1). Typical Value = 0.
tf2
Rate feedback lag time constant (Tf2). Typical Value = 0.
efdmax
Exciter maximum limit (Efdmax). Typical Value = 8.
efdmin
Exciter minimum limit (Efdmin). Typical Value = -0.87.
ke
Exciter constant (Ke). Typical Value = 0.
te
Exciter time constant (Te). Typical Value = 0.
e1
Field voltage value 1 (E1). Typical Value = 0.
se1
Saturation factor at E1 (Se1). Typical Value = 0.
e2
Field voltage value 2 (E2). Typical Value = 0.
se2
Saturation factor at E2 (Se2). Typical Value = 0.
kp
Potential source gain (Kp). Typical Value = 6.5.
ki
Current source gain (Ki). Typical Value = 0.
kc
Exciter regulation factor (Kc). Typical Value = 0.08.
ExcREXS
General Purpose Rotating Excitation System Model. This model can be used to represent a wide range of excitation systems whose DC power source is an AC or DC generator. It encompasses IEEE type AC1, AC2, DC1, and DC2 excitation system models.
e1
Field voltage value 1 (E1). Typical Value = 3.
e2
Field voltage value 2 (E2). Typical Value = 4.
fbf
Rate feedback signal flag (Fbf). Typical Value = fieldCurrent.
flimf
Limit type flag (Flimf). Typical Value = 0.
kc
Rectifier regulation factor (Kc). Typical Value = 0.05.
kd
Exciter regulation factor (Kd). Typical Value = 2.
ke
Exciter field proportional constant (Ke). Typical Value = 1.
kefd
Field voltage feedback gain (Kefd). Typical Value = 0.
kf
Rate feedback gain (Kf). Typical Value = 0.05.
kh
Field voltage controller feedback gain (Kh). Typical Value = 0.
kii
Field Current Regulator Integral Gain (Kii). Typical Value = 0.
kip
Field Current Regulator Proportional Gain (Kip). Typical Value = 1.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
kvi
Voltage Regulator Integral Gain (Kvi). Typical Value = 0.
kvp
Voltage Regulator Proportional Gain (Kvp). Typical Value = 2800.
kvphz
V/Hz limiter gain (Kvphz). Typical Value = 0.
nvphz
Pickup speed of V/Hz limiter (Nvphz). Typical Value = 0.
se1
Saturation factor at E1 (Se1). Typical Value = 0.0001.
se2
Saturation factor at E2 (Se2). Typical Value = 0.001.
ta
Voltage Regulator time constant (Ta). Typical Value = 0.01.
tb1
Lag time constant (Tb1). Typical Value = 0.
tb2
Lag time constant (Tb2). Typical Value = 0.
tc1
Lead time constant (Tc1). Typical Value = 0.
tc2
Lead time constant (Tc2). Typical Value = 0.
te
Exciter field time constant (Te). Typical Value = 1.2.
tf
Rate feedback time constant (Tf). Typical Value = 1.
tf1
Feedback lead time constant (Tf1). Typical Value = 0.
tf2
Feedback lag time constant (Tf2). Typical Value = 0.
tp
Field current Bridge time constant (Tp). Typical Value = 0.
vcmax
Maximum compounding voltage (Vcmax). Typical Value = 0.
vfmax
Maximum Exciter Field Current (Vfmax). Typical Value = 47.
vfmin
Minimum Exciter Field Current (Vfmin). Typical Value = -20.
vimax
Voltage Regulator Input Limit (Vimax). Typical Value = 0.1.
vrmax
Maximum controller output (Vrmax). Typical Value = 47.
vrmin
Minimum controller output (Vrmin). Typical Value = -20.
xc
Exciter compounding reactance (Xc). Typical Value = 0.
ExcSCRX
Simple excitation system model representing generic characteristics of many excitation systems; intended for use where negative field current may be a problem.
tatb
Ta/Tb - gain reduction ratio of lag-lead element (TaTb). The parameter Ta is not defined explicitly. Typical Value = 0.1.
tb
Denominator time constant of lag-lead block (Tb). Typical Value = 10.
k
Gain (K) (>0). Typical Value = 200.
te
Time constant of gain block (Te) (>0). Typical Value = 0.02.
emin
Minimum field voltage output (Emin). Typical Value = 0.
emax
Maximum field voltage output (Emax). Typical Value = 5.
cswitch
Power source switch (Cswitch).
true = fixed voltage of 1.0 PU
false = generator terminal voltage.
rcrfd
Rc/Rfd - ratio of field discharge resistance to field winding resistance (RcRfd). Typical Value = 0.
ExcSEXS
Simplified Excitation System Model.
tatb
Ta/Tb - gain reduction ratio of lag-lead element (TaTb). Typical Value = 0.1.
tb
Denominator time constant of lag-lead block (Tb). Typical Value = 10.
k
Gain (K) (>0). Typical Value = 100.
te
Time constant of gain block (Te). Typical Value = 0.05.
emin
Minimum field voltage output (Emin). Typical Value = -5.
emax
Maximum field voltage output (Emax). Typical Value = 5.
kc
PI controller gain (Kc). Typical Value = 0.08.
tc
PI controller phase lead time constant (Tc). Typical Value = 0.
efdmin
Field voltage clipping minimum limit (Efdmin). Typical Value = -5.
efdmax
Field voltage clipping maximum limit (Efdmax). Typical Value = 5.
ExcSK
Slovakian Excitation System Model. UEL and secondary voltage control are included in this model. When this model is used, there cannot be a separate underexcitation limiter or VAr controller model.
efdmax
Field voltage clipping limit (Efdmax).
efdmin
Field voltage clipping limit (Efdmin).
emax
Maximum field voltage output (Emax). Typical Value = 20.
emin
Minimum field voltage output (Emin). Typical Value = -20.
k
Gain (K). Typical Value = 1.
k1
Parameter of underexcitation limit (K1). Typical Value = 0.1364.
k2
Parameter of underexcitation limit (K2). Typical Value = -0.3861.
kc
PI controller gain (Kc). Typical Value = 70.
kce
Rectifier regulation factor (Kce). Typical Value = 0.
kd
Exciter internal reactance (Kd). Typical Value = 0.
kgob
P controller gain (Kgob). Typical Value = 10.
kp
PI controller gain (Kp). Typical Value = 1.
kqi
PI controller gain of integral component (Kqi). Typical Value = 0.
kqob
Rate of rise of the reactive power (Kqob).
kqp
PI controller gain (Kqp). Typical Value = 0.
nq
Dead band of reactive power (nq). Determines the range of sensitivity. Typical Value = 0.001.
qconoff
Secondary voltage control state (Qc_on_off).
true = secondary voltage control is ON
false = secondary voltage control is OFF.
Typical Value = false.
qz
Desired value (setpoint) of reactive power, manual setting (Qz).
remote
Selector to apply automatic calculation in secondary controller model.
true = automatic calculation is activated
false = manual set is active; the use of desired value of reactive power (Qz) is required.
Typical Value = true.
sbase
Apparent power of the unit (Sbase). Unit = MVA. Typical Value = 259.
ApparentPower
Product of the RMS value of the voltage and the RMS value of the current.
CIMDatatype
value
unit
multiplier
tc
PI controller phase lead time constant (Tc). Typical Value = 8.
te
Time constant of gain block (Te). Typical Value = 0.1.
ti
PI controller phase lead time constant (Ti). Typical Value = 2.
tp
Time constant (Tp). Typical Value = 0.1.
tr
Voltage transducer time constant (Tr). Typical Value = 0.01.
uimax
Maximum error (Uimax). Typical Value = 10.
uimin
Minimum error (UImin). Typical Value = -10.
urmax
Maximum controller output (URmax). Typical Value = 10.
urmin
Minimum controller output (URmin). Typical Value = -10.
vtmax
Maximum terminal voltage input (Vtmax). Determines the range of voltage dead band. Typical Value = 1.05.
vtmin
Minimum terminal voltage input (Vtmin). Determines the range of voltage dead band. Typical Value = 0.95.
yp
Maximum output (Yp). Minimum output = 0. Typical Value = 1.
ExcST1A
Modification of an old IEEE ST1A static excitation system without overexcitation limiter (OEL) and underexcitation limiter (UEL).
vimax
Maximum voltage regulator input limit (Vimax). Typical Value = 999.
vimin
Minimum voltage regulator input limit (Vimin). Typical Value = -999.
tc
Voltage regulator time constant (Tc). Typical Value = 1.
tb
Voltage regulator time constant (Tb). Typical Value = 10.
ka
Voltage regulator gain (Ka). Typical Value = 190.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vrmax
Maximum voltage regulator outputs (Vrmax). Typical Value = 7.8.
vrmin
Minimum voltage regulator outputs (Vrmin). Typical Value = -6.7.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.05.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
tc1
Voltage regulator time constant (Tc1). Typical Value = 0.
tb1
Voltage regulator time constant (Tb1). Typical Value = 0.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 999.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -999.
ilr
Exciter output current limit reference (Ilr). Typical Value = 0.
klr
Exciter output current limiter gain (Klr). Typical Value = 0.
xe
Excitation xfmr effective reactance (Xe). Typical Value = 0.04.
ExcST2A
Modified IEEE ST2A static excitation system - another lead-lag block added to match the model defined by WECC.
ka
Voltage regulator gain (Ka). Typical Value = 120.
ta
Voltage regulator time constant (Ta). Typical Value = 0.15.
vrmax
Maximum voltage regulator outputs (Vrmax). Typical Value = 1.
vrmin
Minimum voltage regulator outputs (Vrmin). Typical Value = -1.
ke
Exciter constant related to self-excited field (Ke). Typical Value = 1.
te
Exciter time constant, integration rate associated with exciter control (Te). Typical Value = 0.5.
kf
Excitation control system stabilizer gains (Kf). Typical Value = 0.05.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 0.7.
kp
Potential circuit gain coefficient (Kp). Typical Value = 4.88.
ki
Potential circuit gain coefficient (Ki). Typical Value = 8.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 1.82.
efdmax
Maximum field voltage (Efdmax). Typical Value = 99.
uelin
UEL input (UELin).
true = HV gate
false = add to error signal.
Typical Value = false.
tb
Voltage regulator time constant (Tb). Typical Value = 0.
tc
Voltage regulator time constant (Tc). Typical Value = 0.
ExcST3A
Modified IEEE ST3A static excitation system with added speed multiplier.
vimax
Maximum voltage regulator input limit (Vimax). Typical Value = 0.2.
vimin
Minimum voltage regulator input limit (Vimin). Typical Value = -0.2.
kj
AVR gain (Kj). Typical Value = 200.
tb
Voltage regulator time constant (Tb). Typical Value = 6.67.
tc
Voltage regulator time constant (Tc). Typical Value = 1.
efdmax
Maximum AVR output (Efdmax). Typical Value = 6.9.
km
Forward gain constant of the inner loop field regulator (Km). Typical Value = 7.04.
tm
Forward time constant of inner loop field regulator (Tm). Typical Value = 1.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 1.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = 0.
kg
Feedback gain constant of the inner loop field regulator (Kg). Typical Value = 1.
kp
Potential source gain (Kp) (>0). Typical Value = 4.37.
thetap
Potential circuit phase angle (thetap). Typical Value = 20.
ki
Potential circuit gain coefficient (Ki). Typical Value = 4.83.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 1.1.
xl
Reactance associated with potential source (Xl). Typical Value = 0.09.
vbmax
Maximum excitation voltage (Vbmax). Typical Value = 8.63.
vgmax
Maximum inner loop feedback voltage (Vgmax). Typical Value = 6.53.
ks
Coefficient to allow different usage of the model-speed coefficient (Ks). Typical Value = 0.
ks1
Coefficient to allow different usage of the model-speed coefficient (Ks1). Typical Value = 0.
ExcST4B
Modified IEEE ST4B static excitation system with maximum inner loop feedback gain Vgmax.
kpr
Voltage regulator proportional gain (Kpr). Typical Value = 10.75.
kir
Voltage regulator integral gain (Kir). Typical Value = 10.75.
ta
Voltage regulator time constant (Ta). Typical Value = 0.02.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 1.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -0.87.
kpm
Voltage regulator proportional gain output (Kpm). Typical Value = 1.
kim
Voltage regulator integral gain output (Kim). Typical Value = 0.
vmmax
Maximum inner loop output (Vmmax). Typical Value = 99.
vmmin
Minimum inner loop output (Vmmin). Typical Value = -99.
kg
Feedback gain constant of the inner loop field regulator (Kg). Typical Value = 0.
kp
Potential circuit gain coefficient (Kp). Typical Value = 9.3.
thetap
Potential circuit phase angle (thetap). Typical Value = 0.
ki
Potential circuit gain coefficient (Ki). Typical Value = 0.
kc
Rectifier loading factor proportional to commutating reactance (Kc). Typical Value = 0.113.
xl
Reactance associated with potential source (Xl). Typical Value = 0.124.
vbmax
Maximum excitation voltage (Vbmax). Typical Value = 11.63.
vgmax
Maximum inner loop feedback voltage (Vgmax). Typical Value = 5.8.
uel
Selector (Uel).
true = UEL is part of block diagram
false = UEL is not part of block diagram.
Typical Value = false.
lvgate
Selector (LVgate).
true = LVgate is part of the block diagram
false = LVgate is not part of the block diagram.
Typical Value = false.
ExcST6B
Modified IEEE ST6B static excitation system with PID controller and optional inner feedbacks loop.
ilr
Exciter output current limit reference (Ilr). Typical Value = 4.164.
k1
Selector (K1).
true = feedback is from Ifd
false = feedback is not from Ifd.
Typical Value = true.
kcl
Exciter output current limit adjustment (Kcl). Typical Value = 1.0577.
kff
Pre-control gain constant of the inner loop field regulator (Kff). Typical Value = 1.
kg
Feedback gain constant of the inner loop field regulator (Kg). Typical Value = 1.
kia
Voltage regulator integral gain (Kia). Typical Value = 45.094.
klr
Exciter output current limit adjustment (Kcl). Typical Value = 17.33.
km
Forward gain constant of the inner loop field regulator (Km). Typical Value = 1.
kpa
Voltage regulator proportional gain (Kpa). Typical Value = 18.038.
kvd
Voltage regulator derivative gain (Kvd). Typical Value = 0.
oelin
OEL input selector (OELin). Typical Value = noOELinput.
tg
Feedback time constant of inner loop field voltage regulator (Tg). Typical Value = 0.02.
ts
Rectifier firing time constant (Ts). Typical Value = 0.
tvd
Voltage regulator derivative gain (Tvd). Typical Value = 0.
vamax
Maximum voltage regulator output (Vamax). Typical Value = 4.81.
vamin
Minimum voltage regulator output (Vamin). Typical Value = -3.85.
vilim
Selector (Vilim).
true = Vimin-Vimax limiter is active
false = Vimin-Vimax limiter is not active.
Typical Value = true.
vimax
Maximum voltage regulator input limit (Vimax). Typical Value = 10.
vimin
Minimum voltage regulator input limit (Vimin). Typical Value = -10.
vmult
Selector (Vmult).
true = multiply regulator output by terminal voltage
false = do not multiply regulator output by terminal voltage.
Typical Value = true.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 4.81.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -3.85.
xc
Excitation source reactance (Xc). Typical Value = 0.05.
ExcST7B
Modified IEEE ST7B static excitation system without stator current limiter (SCL) and current compensator (DROOP) inputs.
kh
High-value gate feedback gain (Kh). Typical Value = 1.
kia
Voltage regulator integral gain (Kia). Typical Value = 1.
kl
Low-value gate feedback gain (Kl). Typical Value = 1.
kpa
Voltage regulator proportional gain (Kpa). Typical Value = 40.
oelin
OEL input selector (OELin). Typical Value = noOELinput.
tb
Regulator lag time constant (Tb). Typical Value = 1.
tc
Regulator lead time constant (Tc). Typical Value = 1.
tf
Excitation control system stabilizer time constant (Tf). Typical Value = 1.
tg
Feedback time constant of inner loop field voltage regulator (Tg). Typical Value = 1.
tia
Feedback time constant (Tia). Typical Value = 3.
ts
Rectifier firing time constant (Ts). Typical Value = 0.
uelin
UEL input selector (UELin). Typical Value = noUELinput.
vmax
Maximum voltage reference signal (Vmax). Typical Value = 1.1.
vmin
Minimum voltage reference signal (Vmin). Typical Value = 0.9.
vrmax
Maximum voltage regulator output (Vrmax). Typical Value = 5.
vrmin
Minimum voltage regulator output (Vrmin). Typical Value = -4.5.
OverexcitationLimiterDynamics
Overexcitation limiters (OELs) are also referred to as maximum excitation limiters and field current limiters. The possibility of voltage collapse in stressed power systems increases the importance of modelling these limiters in studies of system conditions that cause machines to operate at high levels of excitation for a sustained period, such as voltage collapse or system-islanding. Such events typically occur over a long time frame compared with transient or small-signal stability simulations.
OverexcitationLimiterDynamics
OOverexcitation limiter function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
OverexcLimIEEE
The over excitation limiter model is intended to represent the significant features of OELs necessary for some large-scale system studies. It is the result of a pragmatic approach to obtain a model that can be widely applied with attainable data from generator owners. An attempt to include all variations in the functionality of OELs and duplicate how they interact with the rest of the excitation systems would likely result in a level of application insufficient for the studies for which they are intended.
Reference: IEEE OEL 421.5-2005 Section 9.
itfpu
OEL timed field current limiter pickup level (ITFPU). Typical Value = 1.05.
ifdmax
OEL instantaneous field current limit (IFDMAX). Typical Value = 1.5.
ifdlim
OEL timed field current limit (IFDLIM). Typical Value = 1.05.
hyst
OEL pickup/drop-out hysteresis (HYST). Typical Value = 0.03.
kcd
OEL cooldown gain (KCD). Typical Value = 1.
kramp
OEL ramped limit rate (KRAMP). Unit = PU/sec. Typical Value = 10.
OverexcLim2
Different from LimIEEEOEL, LimOEL2 has a fixed pickup threshold and reduces the excitation set-point by mean of non-windup integral regulator.
Irated is the rated machine excitation current (calculated from nameplate conditions: Vnom, Pnom, CosPhinom).
koi
Gain Over excitation limiter (KOI). Typical Value = 0.1.
voimax
Maximum error signal (VOIMAX). Typical Value = 0.
voimin
Minimum error signal (VOIMIN). Typical Value = -9999.
ifdlim
Limit value of rated field current (IFDLIM). Typical Value = 1.05.
OverexcLimX1
Field voltage over excitation limiter.
efdrated
Rated field voltage (EFDRATED). Typical Value = 1.05.
efd1
Low voltage point on the inverse time characteristic (EFD1). Typical Value = 1.1.
t1
Time to trip the exciter at the low voltage point on the inverse time characteristic (TIME1). Typical Value = 120.
efd2
Mid voltage point on the inverse time characteristic (EFD2). Typical Value = 1.2.
t2
Time to trip the exciter at the mid voltage point on the inverse time characteristic (TIME2). Typical Value = 40.
efd3
High voltage point on the inverse time characteristic (EFD3). Typical Value = 1.5.
t3
Time to trip the exciter at the high voltage point on the inverse time characteristic (TIME3). Typical Value = 15.
efddes
Desired field voltage (EFDDES). Typical Value = 0.9.
kmx
Gain (KMX). Typical Value = 0.01.
vlow
Low voltage limit (VLOW) (>0).
OverexcLimX2
Field Voltage or Current overexcitation limiter designed to protect the generator field of an AC machine with automatic excitation control from overheating due to prolonged overexcitation.
m
(m).
true = IFD limiting
false = EFD limiting.
efdrated
Rated field voltage if m=F or field current if m=T (EFDRATED). Typical Value = 1.05.
efd1
Low voltage or current point on the inverse time characteristic (EFD1). Typical Value = 1.1.
t1
Time to trip the exciter at the low voltage or current point on the inverse time characteristic (TIME1). Typical Value = 120.
efd2
Mid voltage or current point on the inverse time characteristic (EFD2). Typical Value = 1.2.
t2
Time to trip the exciter at the mid voltage or current point on the inverse time characteristic (TIME2). Typical Value = 40.
efd3
High voltage or current point on the inverse time characteristic (EFD3). Typical Value = 1.5.
t3
Time to trip the exciter at the high voltage or current point on the inverse time characteristic (TIME3). Typical Value = 15.
efddes
Desired field voltage if m=F or field current if m=T (EFDDES). Typical Value = 1.
kmx
Gain (KMX). Typical Value = 0.002.
vlow
Low voltage limit (VLOW) (>0).
UnderexcitationLimiterDynamics
Underexcitation limiters (UELs) act to boost excitation. The UEL typically senses either a combination of voltage and current of the synchronous machine or a combination of real and reactive power. Some UELs utilize a temperature or pressure recalibration feature, in which the UEL characteristic is shifted depending upon the generator cooling gas temperature or pressure.
UnderexcitationLimiterDynamics
Underexcitation limiter function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
UnderexcLimIEEE1
The class represents the Type UEL1 model which has a circular limit boundary when plotted in terms of machine reactive power vs. real power output.
Reference: IEEE UEL1 421.5-2005 Section 10.1.
kur
UEL radius setting (KUR). Typical Value = 1.95.
kuc
UEL center setting (KUC). Typical Value = 1.38.
kuf
UEL excitation system stabilizer gain (KUF). Typical Value = 3.3.
vurmax
UEL maximum limit for radius phasor magnitude (VURMAX). Typical Value = 5.8.
vucmax
UEL maximum limit for operating point phasor magnitude (VUCMAX). Typical Value = 5.8.
kui
UEL integral gain (KUI). Typical Value = 0.
kul
UEL proportional gain (KUL). Typical Value = 100.
vuimax
UEL integrator output maximum limit (VUIMAX).
vuimin
UEL integrator output minimum limit (VUIMIN).
tu1
UEL lead time constant (TU1). Typical Value = 0.
tu2
UEL lag time constant (TU2). Typical Value = 0.05.
tu3
UEL lead time constant (TU3). Typical Value = 0.
tu4
UEL lag time constant (TU4). Typical Value = 0.
vulmax
UEL output maximum limit (VULMAX). Typical Value = 18.
vulmin
UEL output minimum limit (VULMIN). Typical Value = -18.
UnderexcLimIEEE2
The class represents the Type UEL2 which has either a straight-line or multi-segment characteristic when plotted in terms of machine reactive power output vs. real power output.
Reference: IEEE UEL2 421.5-2005 Section 10.2. (Limit characteristic lookup table shown in Figure 10.4 (p 32) of the standard).
tuv
Voltage filter time constant (TUV). Typical Value = 5.
tup
Real power filter time constant (TUP). Typical Value = 5.
tuq
Reactive power filter time constant (TUQ). Typical Value = 0.
kui
UEL integral gain (KUI). Typical Value = 0.5.
kul
UEL proportional gain (KUL). Typical Value = 0.8.
vuimax
UEL integrator output maximum limit (VUIMAX). Typical Value = 0.25.
vuimin
UEL integrator output minimum limit (VUIMIN). Typical Value = 0.
kuf
UEL excitation system stabilizer gain (KUF). Typical Value = 0.
kfb
Gain associated with optional integrator feedback input signal to UEL (KFB). Typical Value = 0.
tul
Time constant associated with optional integrator feedback input signal to UEL (TUL). Typical Value = 0.
tu1
UEL lead time constant (TU1). Typical Value = 0.
tu2
UEL lag time constant (TU2). Typical Value = 0.
tu3
UEL lead time constant (TU3). Typical Value = 0.
tu4
UEL lag time constant (TU4). Typical Value = 0.
vulmax
UEL output maximum limit (VULMAX). Typical Value = 0.25.
vulmin
UEL output minimum limit (VULMIN). Typical Value = 0.
p0
Real power values for endpoints (P0). Typical Value = 0.
q0
Reactive power values for endpoints (Q0). Typical Value = -0.31.
p1
Real power values for endpoints (P1). Typical Value = 0.3.
q1
Reactive power values for endpoints (Q1). Typical Value = -0.31.
p2
Real power values for endpoints (P2). Typical Value = 0.6.
q2
Reactive power values for endpoints (Q2). Typical Value = -0.28.
p3
Real power values for endpoints (P3). Typical Value = 0.9.
q3
Reactive power values for endpoints (Q3). Typical Value = -0.21.
p4
Real power values for endpoints (P4). Typical Value = 1.02.
q4
Reactive power values for endpoints (Q4). Typical Value = 0.
p5
Real power values for endpoints (P5).
q5
Reactive power values for endpoints (Q5).
p6
Real power values for endpoints (P6).
q6
Reactive power values for endpoints (Q6).
p7
Real power values for endpoints (P7).
q7
Reactive power values for endpoints (Q7).
p8
Real power values for endpoints (P8).
q8
Reactive power values for endpoints (Q8).
p9
Real power values for endpoints (P9).
q9
Reactive power values for endpoints (Q9).
p10
Real power values for endpoints (P10).
q10
Reactive power values for endpoints (Q10).
k1
UEL terminal voltage exponent applied to real power input to UEL limit look-up table (k1). Typical Value = 2.
k2
UEL terminal voltage exponent applied to reactive power output from UEL limit look-up table (k2). Typical Value = 2.
UnderexcLim2Simplified
This model can be derived from UnderexcLimIEEE2.
The limit characteristic (look –up table) is a single straight-line, the same as UnderexcLimIEEE2 (see Figure 10.4 (p 32), IEEE 421.5-2005 Section 10.2).
q0
Segment Q initial point (Q0). Typical Value = -0.31.
q1
Segment Q end point (Q1). Typical Value = -0.1.
p0
Segment P initial point (P0). Typical Value = 0.
p1
Segment P end point (P1). Typical Value = 1.
kui
Gain Under excitation limiter (Kui). Typical Value = 0.1.
vuimin
Minimum error signal (VUImin). Typical Value = 0.
vuimax
Maximum error signal (VUImax). Typical Value = 1.
UnderexcLimX1
Allis-Chalmers minimum excitation limiter.
kf2
Differential gain (Kf2).
tf2
Differential time constant (Tf2) (>0).
km
Minimum excitation limit gain (Km).
tm
Minimum excitation limit time constant (Tm).
melmax
Minimum excitation limit value (MELMAX).
k
Minimum excitation limit slope (K) (>0).
UnderexcLimX2
Westinghouse minimum excitation limiter.
kf2
Differential gain (Kf2).
tf2
Differential time constant (Tf2) (>0).
km
Minimum excitation limit gain (Km).
tm
Minimum excitation limit time constant (Tm).
melmax
Minimum excitation limit value (MELMAX).
qo
Excitation center setting (Qo).
r
Excitation radius (R).
PowerSystemStabilizerDynamics
The power system stabilizer (PSS) model provides an input (Vs) to the excitation system model to improve damping of system oscillations. A variety of input signals may be used depending on the particular design.
PowerSystemStabilizerDynamics
Power system stabilizer function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
PssIEEE1A
The class represents IEEE Std 421.5-2005 type PSS1A power system stabilizer model. PSS1A is the generalized form of a PSS with a single input. Some common stabilizer input signals are speed, frequency, and power.
Reference: IEEE 1A 421.5-2005 Section 8.1.
inputSignalType
Type of input signal. Typical Value = rotorAngularFrequencyDeviation.
InputSignalKind
Input signal type. In Dynamics modelling, commonly represented by j parameter.
rotorSpeed
Input signal is rotor or shaft speed (angular frequency).
rotorAngularFrequencyDeviation
Input signal is rotor or shaft angular frequency deviation.
busFrequency
Input signal is bus voltage frequency. This could be a terminal frequency or remote frequency.
busFrequencyDeviation
Input signal is deviation of bus voltage frequency. This could be a terminal frequency deviation or remote frequency deviation.
generatorElectricalPower
Input signal is generator electrical power on rated S.
generatorAcceleratingPower
Input signal is generating accelerating power.
busVoltage
Input signal is bus voltage. This could be a terminal voltage or remote voltage.
busVoltageDerivative
Input signal is derivative of bus voltage. This could be a terminal voltage derivative or remote voltage derivative.
branchCurrent
Input signal is amplitude of remote branch current.
fieldCurrent
Input signal is generator field current.
a1
PSS signal conditioning frequency filter constant (A1). Typical Value = 0.061.
a2
PSS signal conditioning frequency filter constant (A2). Typical Value = 0.0017.
t1
Lead/lag time constant (T1). Typical Value = 0.3.
t2
Lead/lag time constant (T2). Typical Value = 0.03.
t3
Lead/lag time constant (T3). Typical Value = 0.3.
t4
Lead/lag time constant (T4). Typical Value = 0.03.
t5
Washout time constant (T5). Typical Value = 10.
t6
Transducer time constant (T6). Typical Value = 0.01.
ks
Stabilizer gain (Ks). Typical Value = 5.
vrmax
Maximum stabilizer output (Vrmax). Typical Value = 0.05.
vrmin
Minimum stabilizer output (Vrmin). Typical Value = -0.05.
PssIEEE2B
The class represents IEEE Std 421.5-2005 type PSS2B power system stabilizer model. This stabilizer model is designed to represent a variety of dual-input stabilizers, which normally use combinations of power and speed or frequency to derive the stabilizing signal.
Reference: IEEE 2B 421.5-2005 Section 8.2.
inputSignal1Type
Type of input signal #1. Typical Value = rotorSpeed.
inputSignal2Type
Type of input signal #2. Typical Value = generatorElectricalPower.
vsi1max
Input signal #1 max limit (Vsi1max). Typical Value = 2.
vsi1min
Input signal #1 min limit (Vsi1min). Typical Value = -2.
tw1
First washout on signal #1 (Tw1). Typical Value = 2.
tw2
Second washout on signal #1 (Tw2). Typical Value = 2.
vsi2max
Input signal #2 max limit (Vsi2max). Typical Value = 2.
vsi2min
Input signal #2 min limit (Vsi2min). Typical Value = -2.
tw3
First washout on signal #2 (Tw3). Typical Value = 2.
tw4
Second washout on signal #2 (Tw4). Typical Value = 0.
t1
Lead/lag time constant (T1). Typical Value = 0.12.
t2
Lead/lag time constant (T2). Typical Value = 0.02.
t3
Lead/lag time constant (T3). Typical Value = 0.3.
t4
Lead/lag time constant (T4). Typical Value = 0.02.
t6
Time constant on signal #1 (T6). Typical Value = 0.
t7
Time constant on signal #2 (T7). Typical Value = 2.
t8
Lead of ramp tracking filter (T8). Typical Value = 0.2.
t9
Lag of ramp tracking filter (T9). Typical Value = 0.1.
t10
Lead/lag time constant (T10). Typical Value = 0.
t11
Lead/lag time constant (T11). Typical Value = 0.
ks1
Stabilizer gain (Ks1). Typical Value = 12.
ks2
Gain on signal #2 (Ks2). Typical Value = 0.2.
ks3
Gain on signal #2 input before ramp-tracking filter (Ks3). Typical Value = 1.
n
Order of ramp tracking filter (N). Typical Value = 1.
m
Denominator order of ramp tracking filter (M). Typical Value = 5.
vstmax
Stabilizer output max limit (Vstmax). Typical Value = 0.1.
vstmin
Stabilizer output min limit (Vstmin). Typical Value = -0.1.
PssIEEE3B
The class represents IEEE Std 421.5-2005 type PSS3B power system stabilizer model. The PSS model PSS3B has dual inputs of electrical power and rotor angular frequency deviation. The signals are used to derive an equivalent mechanical power signal.
Reference: IEEE 3B 421.5-2005 Section 8.3.
inputSignal1Type
Type of input signal #1. Typical Value = generatorElectricalPower.
inputSignal2Type
Type of input signal #2. Typical Value = rotorSpeed.
t1
Transducer time constant (T1). Typical Value = 0.012.
t2
Transducer time constant (T2). Typical Value = 0.012.
tw1
Washout time constant (Tw1). Typical Value = 0.3.
tw2
Washout time constant (Tw2). Typical Value = 0.3.
tw3
Washout time constant (Tw3). Typical Value = 0.6.
ks1
Gain on signal # 1 (Ks1). Typical Value = -0.602.
ks2
Gain on signal # 2 (Ks2). Typical Value = 30.12.
a1
Notch filter parameter (A1). Typical Value = 0.359.
a2
Notch filter parameter (A2). Typical Value = 0.586.
a3
Notch filter parameter (A3). Typical Value = 0.429.
a4
Notch filter parameter (A4). Typical Value = 0.564.
a5
Notch filter parameter (A5). Typical Value = 0.001.
a6
Notch filter parameter (A6). Typical Value = 0.
a7
Notch filter parameter (A7). Typical Value = 0.031.
a8
Notch filter parameter (A8). Typical Value = 0.
vstmax
Stabilizer output max limit (Vstmax). Typical Value = 0.1.
vstmin
Stabilizer output min limit (Vstmin). Typical Value = -0.1.
PssIEEE4B
The class represents IEEE Std 421.5-2005 type PSS2B power system stabilizer model. The PSS4B model represents a structure based on multiple working frequency bands. Three separate bands, respectively dedicated to the low-, intermediate- and high-frequency modes of oscillations, are used in this delta-omega (speed input) PSS.
Reference: IEEE 4B 421.5-2005 Section 8.4.
bwh1
Notch filter 1 (high-frequency band): Three dB bandwidth (Bwi).
bwh2
Notch filter 2 (high-frequency band): Three dB bandwidth (Bwi).
bwl1
Notch filter 1 (low-frequency band): Three dB bandwidth (Bwi).
bwl2
Notch filter 2 (low-frequency band): Three dB bandwidth (Bwi).
kh
High band gain (KH). Typical Value = 120.
kh1
High band differential filter gain (KH1). Typical Value = 66.
kh11
High band first lead-lag blocks coefficient (KH11). Typical Value = 1.
kh17
High band first lead-lag blocks coefficient (KH17). Typical Value = 1.
kh2
High band differential filter gain (KH2). Typical Value = 66.
ki
Intermediate band gain (KI). Typical Value = 30.
ki1
Intermediate band differential filter gain (KI1). Typical Value = 66.
ki11
Intermediate band first lead-lag blocks coefficient (KI11). Typical Value = 1.
ki17
Intermediate band first lead-lag blocks coefficient (KI17). Typical Value = 1.
ki2
Intermediate band differential filter gain (KI2). Typical Value = 66.
kl
Low band gain (KL). Typical Value = 7.5.
kl1
Low band differential filter gain (KL1). Typical Value = 66.
kl11
Low band first lead-lag blocks coefficient (KL11). Typical Value = 1.
kl17
Low band first lead-lag blocks coefficient (KL17). Typical Value = 1.
kl2
Low band differential filter gain (KL2). Typical Value = 66.
omeganh1
Notch filter 1 (high-frequency band): filter frequency (omegani).
omeganh2
Notch filter 2 (high-frequency band): filter frequency (omegani).
omeganl1
Notch filter 1 (low-frequency band): filter frequency (omegani).
omeganl2
Notch filter 2 (low-frequency band): filter frequency (omegani).
th1
High band time constant (TH1). Typical Value = 0.01513.
th10
High band time constant (TH10). Typical Value = 0.
th11
High band time constant (TH11). Typical Value = 0.
th12
High band time constant (TH12). Typical Value = 0.
th2
High band time constant (TH2). Typical Value = 0.01816.
th3
High band time constant (TH3). Typical Value = 0.
th4
High band time constant (TH4). Typical Value = 0.
th5
High band time constant (TH5). Typical Value = 0.
th6
High band time constant (TH6). Typical Value = 0.
th7
High band time constant (TH7). Typical Value = 0.01816.
th8
High band time constant (TH8). Typical Value = 0.02179.
th9
High band time constant (TH9). Typical Value = 0.
ti1
Intermediate band time constant (TI1). Typical Value = 0.173.
ti10
Intermediate band time constant (TI11). Typical Value = 0.
ti11
Intermediate band time constant (TI11). Typical Value = 0.
ti12
Intermediate band time constant (TI2). Typical Value = 0.
ti2
Intermediate band time constant (TI2). Typical Value = 0.2075.
ti3
Intermediate band time constant (TI3). Typical Value = 0.
ti4
Intermediate band time constant (TI4). Typical Value = 0.
ti5
Intermediate band time constant (TI5). Typical Value = 0.
ti6
Intermediate band time constant (TI6). Typical Value = 0.
ti7
Intermediate band time constant (TI7). Typical Value = 0.2075.
ti8
Intermediate band time constant (TI8). Typical Value = 0.2491.
ti9
Intermediate band time constant (TI9). Typical Value = 0.
tl1
Low band time constant (TL1). Typical Value = 1.73.
tl10
Low band time constant (TL10). Typical Value = 0.
tl11
Low band time constant (TL11). Typical Value = 0.
tl12
Low band time constant (TL12). Typical Value = 0.
tl2
Low band time constant (TL2). Typical Value = 2.075.
tl3
Low band time constant (TL3). Typical Value = 0.
tl4
Low band time constant (TL4). Typical Value = 0.
tl5
Low band time constant (TL5). Typical Value = 0.
tl6
Low band time constant (TL6). Typical Value = 0.
tl7
Low band time constant (TL7). Typical Value = 2.075.
tl8
Low band time constant (TL8). Typical Value = 2.491.
tl9
Low band time constant (TL9). Typical Value = 0.
vhmax
High band output maximum limit (VHmax). Typical Value = 0.6.
vhmin
High band output minimum limit (VHmin). Typical Value = -0.6.
vimax
Intermediate band output maximum limit (VImax). Typical Value = 0.6.
vimin
Intermediate band output minimum limit (VImin). Typical Value = -0.6.
vlmax
Low band output maximum limit (VLmax). Typical Value = 0.075.
vlmin
Low band output minimum limit (VLmin). Typical Value = -0.075.
vstmax
PSS output maximum limit (VSTmax). Typical Value = 0.15.
vstmin
PSS output minimum limit (VSTmin). Typical Value = -0.15.
Pss1
Italian PSS - three input PSS (speed, frequency, power).
kw
Shaft speed power input gain (KW). Typical Value = 0.
kf
Frequency power input gain (KF). Typical Value = 5.
kpe
Electric power input gain (KPE). Typical Value = 0.3.
pmin
Minimum power PSS enabling (PMIN). Typical Value = 0.25.
ks
PSS gain (KS). Typical Value = 1.
vsmn
Stabilizer output max limit (VSMN). Typical Value = -0.06.
vsmx
Stabilizer output min limit (VSMX). Typical Value = 0.06.
tpe
Electric power filter time constant (TPE). Typical Value = 0.05.
t5
Washout (T5). Typical Value = 3.5.
t6
Filter time constant (T6). Typical Value = 0.
t7
Lead/lag time constant (T7). Typical Value = 0.
t8
Lead/lag time constant (T8). Typical Value = 0.
t9
Lead/lag time constant (T9). Typical Value = 0.
t10
Lead/lag time constant (T10). Typical Value = 0.
vadat
Signal selector (VadAt).
true = closed (Generator Power is greater than Pmin)
false = open (Pe is smaller than Pmin).
Typical Value = true.
Pss1A
Single input power system stabilizer. It is a modified version in order to allow representation of various vendors' implementations on PSS type 1A.
inputSignalType
Type of input signal.
a1
Notch filter parameter (A1).
a2
Notch filter parameter (A2).
t1
Lead/lag time constant (T1).
t2
Lead/lag time constant (T2).
t3
Lead/lag time constant (T3).
t4
Lead/lag time constant (T4).
t5
Washout time constant (T5).
t6
Transducer time constant (T6).
ks
Stabilizer gain (Ks).
vrmax
Maximum stabilizer output (Vrmax).
vrmin
Minimum stabilizer output (Vrmin).
vcu
Stabilizer input cutoff threshold (Vcu).
vcl
Stabilizer input cutoff threshold (Vcl).
a3
Notch filter parameter (A3).
a4
Notch filter parameter (A4).
a5
Notch filter parameter (A5).
a6
Notch filter parameter (A6).
a7
Notch filter parameter (A7).
a8
Notch filter parameter (A8).
kd
Selector (Kd).
true = e-sTdelay used
false = e-sTdelay not used.
tdelay
Time constant (Tdelay).
Pss2B
Modified IEEE PSS2B Model. Extra lead/lag (or rate) block added at end (up to 4 lead/lags total).
inputSignal1Type
Type of input signal #1. Typical Value = rotorSpeed.
inputSignal2Type
Type of input signal #2. Typical Value = generatorElectricalPower.
vsi1max
Input signal #1 max limit (Vsi1max). Typical Value = 2.
vsi1min
Input signal #1 min limit (Vsi1min). Typical Value = -2.
tw1
First washout on signal #1 (Tw1). Typical Value = 2.
tw2
Second washout on signal #1 (Tw2). Typical Value = 2.
vsi2max
Input signal #2 max limit (Vsi2max). Typical Value = 2.
vsi2min
Input signal #2 min limit (Vsi2min). Typical Value = -2.
tw3
First washout on signal #2 (Tw3). Typical Value = 2.
tw4
Second washout on signal #2 (Tw4). Typical Value = 0.
t1
Lead/lag time constant (T1). Typical Value = 0.12.
t2
Lead/lag time constant (T2). Typical Value = 0.02.
t3
Lead/lag time constant (T3). Typical Value = 0.3.
t4
Lead/lag time constant (T4). Typical Value = 0.02.
t6
Time constant on signal #1 (T6). Typical Value = 0.
t7
Time constant on signal #2 (T7). Typical Value = 2.
t8
Lead of ramp tracking filter (T8). Typical Value = 0.2.
t9
Lag of ramp tracking filter (T9). Typical Value = 0.1.
t10
Lead/lag time constant (T10). Typical Value = 0.
t11
Lead/lag time constant (T11). Typical Value = 0.
ks1
Stabilizer gain (Ks1). Typical Value = 12.
ks2
Gain on signal #2 (Ks2). Typical Value = 0.2.
ks3
Gain on signal #2 input before ramp-tracking filter (Ks3). Typical Value = 1.
ks4
Gain on signal #2 input after ramp-tracking filter (Ks4). Typical Value = 1.
n
Order of ramp tracking filter (N). Typical Value = 1.
m
Denominator order of ramp tracking filter (M). Typical Value = 5.
vstmax
Stabilizer output max limit (Vstmax). Typical Value = 0.1.
vstmin
Stabilizer output min limit (Vstmin). Typical Value = -0.1.
a
Numerator constant (a). Typical Value = 1.
ta
Lead constant (Ta). Typical Value = 0.
tb
Lag time constant (Tb). Typical Value = 0.
Pss2ST
PTI Microprocessor-Based Stabilizer type 1.
inputSignal1Type
Type of input signal #1. Typical Value = rotorAngularFrequencyDeviation.
inputSignal2Type
Type of input signal #2. Typical Value = generatorElectricalPower.
k1
Gain (K1).
k2
Gain (K2).
t1
Time constant (T1).
t2
Time constant (T2).
t3
Time constant (T3).
t4
Time constant (T4).
t5
Time constant (T5).
t6
Time constant (T6).
t7
Time constant (T7).
t8
Time constant (T8).
t9
Time constant (T9).
t10
Time constant (T10).
lsmax
Limiter (Lsmax).
lsmin
Limiter (Lsmin).
vcu
Cutoff limiter (Vcu).
vcl
Cutoff limiter (Vcl).
Pss5
Italian PSS - Detailed PSS.
kpe
Electric power input gain (KPE). Typical Value = 0.3.
kf
Frequency/shaft speed input gain (KF). Typical Value = 5.
isfreq
Selector for Frequency/shaft speed input (IsFreq).
true = speed
false = frequency.
Typical Value = true.
kpss
PSS gain (KPSS). Typical Value = 1.
ctw2
Selector for Second washout enabling (CTW2).
true = second washout filter is bypassed
false = second washout filter in use.
Typical Value = true.
tw1
First WashOut (Tw1). Typical Value = 3.5.
tw2
Second WashOut (Tw2). Typical Value = 0.
tl1
Lead/lag time constant (TL1). Typical Value = 0.
tl2
Lead/lag time constant (TL2). Typical Value = 0.
tl3
Lead/lag time constant (TL3). Typical Value = 0.
tl4
Lead/lag time constant (TL4). Typical Value = 0.
vsmn
Stabilizer output max limit (VSMN). Typical Value = -0.1.
vsmx
Stabilizer output min limit (VSMX). Typical Value = 0.1.
tpe
Electric power filter time constant (TPE). Typical Value = 0.05.
pmm
Minimum power PSS enabling (Pmn). Typical Value = 0.25.
deadband
Stabilizer output dead band (DeadBand). Typical Value = 0.
vadat
Signal selector (VadAtt).
true = closed (Generator Power is greater than Pmin)
false = open (Pe is smaller than Pmin).
Typical Value = true.
PssELIN2
Power system stabilizer typically associated with ExcELIN2 (though PssIEEE2B or Pss2B can also be used).
ts1
Time constant (Ts1). Typical Value = 0.
ts2
Time constant (Ts2). Typical Value = 1.
ts3
Time constant (Ts3). Typical Value = 1.
ts4
Time constant (Ts4). Typical Value = 0.1.
ts5
Time constant (Ts5). Typical Value = 0.
ts6
Time constant (Ts6). Typical Value = 1.
ks1
Gain (Ks1). Typical Value = 1.
ks2
Gain (Ks2). Typical Value = 0.1.
ppss
Coefficient (p_PSS) (>=0 and <=4). Typical Value = 0.1.
apss
Coefficient (a_PSS). Typical Value = 0.1.
psslim
PSS limiter (psslim). Typical Value = 0.1.
PssPTIST1
PTI Microprocessor-Based Stabilizer type 1.
m
(M). M=2*H. Typical Value = 5.
tf
Time constant (Tf). Typical Value = 0.2.
tp
Time constant (Tp). Typical Value = 0.2.
t1
Time constant (T1). Typical Value = 0.3.
t2
Time constant (T2). Typical Value = 1.
t3
Time constant (T3). Typical Value = 0.2.
t4
Time constant (T4). Typical Value = 0.05.
k
Gain (K). Typical Value = 9.
dtf
Time step frequency calculation (Dtf). Typical Value = 0.025.
dtc
Time step related to activation of controls (Dtc). Typical Value = 0.025.
dtp
Time step active power calculation (Dtp). Typical Value = 0.0125.
PssPTIST3
PTI Microprocessor-Based Stabilizer type 3.
m
(M). M=2*H. Typical Value = 5.
tf
Time constant (Tf). Typical Value = 0.2.
tp
Time constant (Tp). Typical Value = 0.2.
t1
Time constant (T1). Typical Value = 0.3.
t2
Time constant (T2). Typical Value = 1.
t3
Time constant (T3). Typical Value = 0.2.
t4
Time constant (T4). Typical Value = 0.05.
k
Gain (K). Typical Value = 9.
dtf
Time step frequency calculation (0.03 for 50 Hz) (Dtf). Typical Value = 0.025.
dtc
Time step related to activation of controls (0.03 for 50 Hz) (Dtc). Typical Value = 0.025.
dtp
Time step active power calculation (0.015 for 50 Hz) (Dtp). Typical Value = 0.0125.
t5
Time constant (T5).
t6
Time constant (T6).
a0
Filter coefficient (A0).
a1
Limiter (Al).
a2
Filter coefficient (A2).
b0
Filter coefficient (B0).
b1
Filter coefficient (B1).
b2
Filter coefficient (B2).
a3
Filter coefficient (A3).
a4
Filter coefficient (A4).
a5
Filter coefficient (A5).
b3
Filter coefficient (B3).
b4
Filter coefficient (B4).
b5
Filter coefficient (B5).
athres
Threshold value above which output averaging will be bypassed (Athres). Typical Value = 0.005.
dl
Limiter (Dl).
al
Limiter (Al).
lthres
Threshold value (Lthres).
pmin
(Pmin).
isw
Digital/analog output switch (Isw).
true = produce analog output
false = convert to digital output, using tap selection table.
nav
Number of control outputs to average (Nav) (1 <= Nav <= 16). Typical Value = 4.
ncl
Number of counts at limit to active limit function (Ncl) (>0).
ncr
Number of counts until reset after limit function is triggered (Ncr).
PssSB4
Power sensitive stabilizer model.
tt
Time constant (Tt).
kx
Gain (Kx).
tx2
Time constant (Tx2).
ta
Time constant (Ta).
tx1
Reset time constant (Tx1).
tb
Time constant (Tb).
tc
Time constant (Tc).
td
Time constant (Td).
te
Time constant (Te).
vsmax
Limiter (Vsmax).
vsmin
Limiter (Vsmin).
PssSH
Model for Siemens “H infinity” power system stabilizer with generator electrical power input.
k
Main gain (K). Typical Value = 1.
k0
Gain 0 (K0). Typical Value = 0.012.
k1
Gain 1 (K1). Typical Value = 0.488.
k2
Gain 2 (K2). Typical Value = 0.064.
k3
Gain 3 (K3). Typical Value = 0.224.
k4
Gain 4 (K4). Typical Value = 0.1.
td
Input time constant (Td). Typical Value = 10.
t1
Time constant 1 (T1). Typical Value = 0.076.
t2
Time constant 2 (T2). Typical Value = 0.086.
t3
Time constant 3 (T3). Typical Value = 1.068.
t4
Time constant 4 (T4). Typical Value = 1.913.
vsmax
Output maximum limit (Vsmax). Typical Value = 0.1.
vsmin
Output minimum limit (Vsmin). Typical Value = -0.1.
PssSK
PSS Slovakian type – three inputs.
k1
Gain P (K1). Typical Value = -0.3.
k2
Gain fe (K2). Typical Value = -0.15.
k3
Gain If (K3). Typical Value = 10.
t1
Denominator time constant (T1). Typical Value = 0.3.
t2
Filter time constant (T2). Typical Value = 0.35.
t3
Denominator time constant (T3). Typical Value = 0.22.
t4
Filter time constant (T4). Typical Value = 0.02.
t5
Denominator time constant (T5). Typical Value = 0.02.
t6
Filter time constant (T6). Typical Value = 0.02.
vsmax
Stabilizer output max limit (Vsmax). Typical Value = 0.4.
vsmin
Stabilizer output min limit (Vsmin). Typical Value = -0.4.
PssWECC
Dual input Power System Stabilizer, based on IEEE type 2, with modified output limiter defined by WECC (Western Electricity Coordinating Council, USA).
inputSignal1Type
Type of input signal #1.
inputSignal2Type
Type of input signal #2.
k1
Input signal 1 gain (K1).
t1
Input signal 1 transducer time constant (T1).
k2
Input signal 2 gain (K2).
t2
Input signal 2 transducer time constant (T2).
t3
Stabilizer washout time constant (T3).
t4
Stabilizer washout time lag constant (T4) (>0).
t5
Lead time constant (T5).
t6
Lag time constant (T6).
t7
Lead time constant (T7).
t8
Lag time constant (T8).
t10
Lag time constant (T10).
t9
Lead time constant (T9).
vsmax
Maximum output signal (Vsmax).
vsmin
Minimum output signal (Vsmin).
vcu
Maximum value for voltage compensator output (VCU).
vcl
Minimum value for voltage compensator output (VCL).
DiscontinuousExcitationControlDynamics
In some particular system configurations, continuous excitation control with terminal voltage and power system stabilizing regulator input signals does not ensure that the potential of the excitation system for improving system stability is fully exploited. For these situations, discontinuous excitation control signals may be employed to enhance stability following large transient disturbances.
For additional information please refer to IEEE Standard 421.5-2005, Section 12.
DiscontinuousExcitationControlDynamics
Discontinuous excitation control function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
DiscExcContIEEEDEC1A
The class represents IEEE Type DEC1A discontinuous excitation control model that boosts generator excitation to a level higher than that demanded by the voltage regulator and stabilizer immediately following a system fault.
Reference: IEEE Standard 421.5-2005 Section 12.2.
vtlmt
Voltage reference (VTLMT). Typical Value = 1.1.
vomax
Limiter (VOMAX). Typical Value = 0.3.
vomin
Limiter (VOMIN). Typical Value = 0.1.
ketl
Terminal voltage limiter gain (KETL). Typical Value = 47.
vtc
Terminal voltage level reference (VTC). Typical Value = 0.95.
val
Regulator voltage reference (VAL). Typical Value = 5.5.
esc
Speed change reference (ESC). Typical Value = 0.0015.
kan
Discontinuous controller gain (KAN). Typical Value = 400.
tan
Discontinuous controller time constant (TAN). Typical Value = 0.08.
tw5
DEC washout time constant (TW5). Typical Value = 5.
vsmax
Limiter (VSMAX). Typical Value = 0.2.
vsmin
Limiter (VSMIN). Typical Value = -0.066.
td
Time constant (TD). Typical Value = 0.03.
tl1
Time constant (TL1). Typical Value = 0.025.
tl2
Time constant (TL2). Typical Value = 1.25.
vtm
Voltage limits (VTM). Typical Value = 1.13.
vtn
Voltage limits (VTN). Typical Value = 1.12.
vanmax
Limiter for Van (VANMAX).
DiscExcContIEEEDEC2A
The class represents IEEE Type DEC2A model for the discontinuous excitation control. This system provides transient excitation boosting via an open-loop control as initiated by a trigger signal generated remotely.
Reference: IEEE Standard 421.5-2005 Section 12.3.
vk
Discontinuous controller input reference (VK).
td1
Discontinuous controller time constant (TD1).
td2
Discontinuous controller washout time constant (TD2).
vdmin
Limiter (VDMIN).
vdmax
Limiter (VDMAX).
DiscExcContIEEEDEC3A
The class represents IEEE Type DEC3A model. In some systems, the stabilizer output is disconnected from the regulator immediately following a severe fault to prevent the stabilizer from competing with action of voltage regulator during the first swing.
Reference: IEEE Standard 421.5-2005 Section 12.4.
vtmin
Terminal undervoltage comparison level (VTMIN).
tdr
Reset time delay (TDR).
PFVArControllerType1Dynamics
Excitation systems for synchronous machines are sometimes supplied with an optional means of automatically adjusting generator output reactive power (VAr) or power factor (PF) to a user-specified value This can be accomplished with either a reactive power or power factor controller or regulator. A reactive power or power factor controller is defined as a PF/VAr controller in IEEE Std 421.1 as “A control function that acts through the reference adjuster to modify the voltage regulator set point to maintain the synchronous machine steady-state power factor or reactive power at a predetermined value.”
For additional information please refer to IEEE Standard 421.5-2005, Section 11.
PFVArControllerType1Dynamics
Power Factor or VAr controller Type I function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
PFVArControllerType1Dynamics
Power Factor or VAr controller Type I model with which this voltage adjuster is associated.
Yes
VoltageAdjusterDynamics
Voltage adjuster model associated with this Power Factor or VA controller Type I model.
VoltageAdjusterDynamics
No
PFVArType1IEEEPFController
The class represents IEEE PF Controller Type 1 which operates by moving the voltage reference directly.
Reference: IEEE Standard 421.5-2005 Section 11.2.
ovex
Overexcitation Flag (OVEX)
true = overexcited
false = underexcited.
tpfc
PF controller time delay (TPFC). Typical Value = 5.
vitmin
Minimum machine terminal current needed to enable pf/var controller (VITMIN).
vpf
Synchronous machine power factor (VPF).
vpfcbw
PF controller dead band (VPFC_BW). Typical Value = 0.05.
vpfref
PF controller reference (VPFREF).
vvtmax
Maximum machine terminal voltage needed for pf/var controller to be enabled (VVTMAX).
vvtmin
Minimum machine terminal voltage needed to enable pf/var controller (VVTMIN).
PFVArType1IEEEVArController
The class represents IEEE VAR Controller Type 1 which operates by moving the voltage reference directly.
Reference: IEEE Standard 421.5-2005 Section 11.3.
tvarc
Var controller time delay (TVARC). Typical Value = 5.
vvar
Synchronous machine power factor (VVAR).
vvarcbw
Var controller dead band (VVARC_BW). Typical Value = 0.02.
vvarref
Var controller reference (VVARREF).
vvtmax
Maximum machine terminal voltage needed for pf/var controller to be enabled (VVTMAX).
vvtmin
Minimum machine terminal voltage needed to enable pf/var controller (VVTMIN).
VoltageAdjusterDynamics
A voltage adjuster is a reference adjuster that uses inputs from a reactive power or power factor controller to modify the voltage regulator set point to maintain the synchronous machine steady-state power factor or reactive power at a predetermined value.
For additional information please refer to IEEE Standard 421.5-2005, Section 11.
VoltageAdjusterDynamics
Voltage adjuster function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
VAdjIEEE
The class represents IEEE Voltage Adjuster which is used to represent the voltage adjuster in either a power factor or var control system.
Reference: IEEE Standard 421.5-2005 Section 11.1.
vadjf
Set high to provide a continuous raise or lower (VADJF).
adjslew
Rate at which output of adjuster changes (ADJ_SLEW). Unit = sec./PU. Typical Value = 300.
vadjmax
Maximum output of the adjuster (VADJMAX). Typical Value = 1.1.
vadjmin
Minimum output of the adjuster (VADJMIN). Typical Value = 0.9.
taon
Time that adjuster pulses are on (TAON). Typical Value = 0.1.
taoff
Time that adjuster pulses are off (TAOFF). Typical Value = 0.5.
PFVArControllerType2Dynamics
A var/pf regulator is defined as “A synchronous machine regulator that functions to maintain the power factor or reactive component of power at a predetermined value.”
For additional information please refer to IEEE Standard 421.5-2005, Section 11.
PFVArControllerType2Dynamics
Power Factor or VAr controller Type II function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
PFVArType2IEEEPFController
The class represents IEEE PF Controller Type 2 which is a summing point type controller and makes up the outside loop of a two-loop system. This controller is implemented as a slow PI type controller. The voltage regulator forms the inner loop and is implemented as a fast controller.
Reference: IEEE Standard 421.5-2005 Section 11.4.
pfref
Power factor reference (PFREF).
vref
Voltage regulator reference (VREF).
vclmt
Maximum output of the pf controller (VCLMT). Typical Value = 0.1.
kp
Proportional gain of the pf controller (KP). Typical Value = 1.
ki
Integral gain of the pf controller (KI). Typical Value = 1.
vs
Generator sensing voltage (VS).
exlon
Overexcitation or under excitation flag (EXLON)
true = 1 (not in the overexcitation or underexcitation state, integral action is active)
false = 0 (in the overexcitation or underexcitation state, so integral action is disabled to allow the limiter to play its role).
PFVArType2IEEEVArController
The class represents IEEE VAR Controller Type 2 which is a summing point type controller. It makes up the outside loop of a two-loop system. This controller is implemented as a slow PI type controller, and the voltage regulator forms the inner loop and is implemented as a fast controller.
Reference: IEEE Standard 421.5-2005 Section 11.5.
qref
Reactive power reference (QREF).
vref
Voltage regulator reference (VREF).
vclmt
Maximum output of the pf controller (VCLMT).
kp
Proportional gain of the pf controller (KP).
ki
Integral gain of the pf controller (KI).
vs
Generator sensing voltage (VS).
exlon
Overexcitation or under excitation flag (EXLON)
true = 1 (not in the overexcitation or underexcitation state, integral action is active)
false = 0 (in the overexcitation or underexcitation state, so integral action is disabled to allow the limiter to play its role).
PFVArType2Common1
Power factor / Reactive power regulator. This model represents the power factor or reactive power controller such as the Basler SCP-250. The controller measures power factor or reactive power (PU on generator rated power) and compares it with the operator's set point.
j
Selector (J).
true = control mode for reactive power
false = control mode for power factor.
kp
Proportional gain (Kp).
ki
Reset gain (Ki).
max
Output limit (max).
ref
Reference value of reactive power or power factor (Ref).
The reference value is initialised by this model. This initialisation may override the value exchanged by this attribute to represent a plant operator's change of the reference setting.
VoltageCompensatorDynamics
Synchronous machine terminal voltage transducer and current compensator models adjust the terminal voltage feedback to the excitation system by adding a quantity that is proportional to the terminal current of the generator. It is linked to a specific generator (synchronous machine).
Several types of compensation are available on most excitation systems. Synchronous machine active and reactive current compensation are the most common. Either reactive droop compensation and/or line-drop compensation may be used, simulating an impedance drop and effectively regulating at some point other than the terminals of the machine. The impedance or range of adjustment and type of compensation should be specified for different types.
Care must be taken to ensure that a consistent pu system is utilized for the compensator parameters and the synchronous machine current base.
For further information see IEEE Standard 421.5-2005, Section 4.
VoltageCompensatorDynamics
Voltage compensator function block whose behaviour is described by reference to a standard model or by definition of a user-defined model.
abstract
VCompIEEEType1
The class represents the terminal voltage transducer and the load compensator as defined in the IEEE Std 421.5-2005, Section 4. This model is common to all excitation system models described in the IEEE Standard.
Reference: IEEE Standard 421.5-2005 Section 4.
rc
Resistive component of compensation of a generator (Rc).
xc
Reactive component of compensation of a generator (Xc).
tr
Time constant which is used for the combined voltage sensing and compensation signal (Tr).
VCompIEEEType2
The class represents the terminal voltage transducer and the load compensator as defined in the IEEE Std 421.5-2005, Section 4. This model is designed to cover the following types of compensation:
- reactive droop
- transformer-drop or line-drop compensation
- reactive differential compensation known also as cross-current compensation.
Reference: IEEE Standard 421.5-2005, Section 4.
tr
Time constant which is used for the combined voltage sensing and compensation signal (Tr).
VcompIEEEType2
The standard IEEE Type 2 voltage compensator of this compensation.
Yes
GenICompensationForGenJ
Compensation of this voltage compensator's generator for current flow out of another generator.
GenICompensationForGenJ
No
GenICompensationForGenJ
This class provides the resistive and reactive components of compensation for the generator associated with the IEEE Type 2 voltage compensator for current flow out of one of the other generators in the interconnection.
rcij
Resistive component of compensation of generator associated with this IEEE Type 2 voltage compensator for current flow out of another generator (Rcij).
xcij
Reactive component of compensation of generator associated with this IEEE Type 2 voltage compensator for current flow out of another generator (Xcij).
WindDynamics
Wind turbines are generally divided into 4 types, which are currently significant in power systems. The 4 types have the following characteristics:
- Type 1: Wind turbine with directly grid connected asynchronous generator with fixed rotor resistance (typically squirrel cage)
- Type 2: Wind turbine with directly grid connected asynchronous generator with variable rotor resistance
- Type 3: Wind turbines with doubly-fed asynchronous generators (directly connected stator and rotor connected through power converter)
- Type 4: Wind turbines connected fully through a power converter.
Models included in this package are according to IEC 61400-27-1.
WindAeroConstIEC
The constant aerodynamic torque model assumes that the aerodynamic torque is constant.
Reference: IEC Standard 61400-27-1 Section 6.6.1.1.
WindGenTurbineType1IEC
Wind turbine type 1 model with which this wind aerodynamic model is associated.
No
WindAeroConstIEC
Wind aerodynamic model associated with this wind turbine type 1 model.
WindAeroConstIEC
Yes
WindAeroLinearIEC
The linearised aerodynamic model.
Reference: IEC Standard 614000-27-1 Section 6.6.1.2.
dpomega
Partial derivative of aerodynamic power with respect to changes in WTR speed (dpomega). It is case dependent parameter.
dptheta
Partial derivative of aerodynamic power with respect to changes in pitch angle (dptheta). It is case dependent parameter.
omegazero
Rotor speed if the wind turbine is not derated (omega0). It is case dependent parameter.
pavail
Available aerodynamic power (pavail). It is case dependent parameter.
thetazero
Pitch angle if the wind turbine is not derated (theta0). It is case dependent parameter.
WindGenTurbineType3IEC
Wind generator type 3 model with which this wind aerodynamic model is associated.
No
WindAeroLinearIEC
Wind aerodynamic model associated with this wind generator type 3 model.
WindAeroLinearIEC
Yes
WindContCurrLimIEC
Current limitation model. The current limitation model combines the physical limits.
Reference: IEC Standard 61400-27-1 Section 6.6.5.7.
imax
Maximum continuous current at the wind turbine terminals (imax). It is type dependent parameter.
imaxdip
Maximum current during voltage dip at the wind turbine terminals (imax,dip). It is project dependent parameter.
mdfslim
Limitation of type 3 stator current (MDFSLim):
- false=0: total current limitation,
- true=1: stator current limitation).
It is type dependent parameter.
mqpri
Prioritisation of q control during LVRT (Mqpri):
- true = 1: reactive power priority,
- false = 0: active power priority.
It is project dependent parameter.
tufilt
Voltage measurement filter time constant (Tufilt). It is type dependent parameter.
WindTurbineType3or4IEC
Wind turbine type 3 or 4 model with which this wind control current limitation model is associated.
No
WindContCurrLimIEC
Wind control current limitation model associated with this wind turbine type 3 or 4 model.
WindContCurrLimIEC
Yes
WindDynamicsLookupTable
The current control limitation model with which this wind dynamics lookup table is associated.
No
WindContCurrLimIEC
The wind dynamics lookup table associated with this current control limitation model.
WindContCurrLimIEC
Yes
WindContPitchAngleIEC
Pitch angle control model.
Reference: IEC Standard 61400-27-1 Section 6.6.5.8.
dthetamax
Maximum pitch positive ramp rate (dthetamax). It is type dependent parameter. Unit = degrees/sec.
dthetamin
Maximum pitch negative ramp rate (dthetamin). It is type dependent parameter. Unit = degrees/sec.
kic
Power PI controller integration gain (KIc). It is type dependent parameter.
kiomega
Speed PI controller integration gain (KIomega). It is type dependent parameter.
kpc
Power PI controller proportional gain (KPc). It is type dependent parameter.
kpomega
Speed PI controller proportional gain (KPomega). It is type dependent parameter.
kpx
Pitch cross coupling gain (KPX). It is type dependent parameter.
thetamax
Maximum pitch angle (thetamax). It is type dependent parameter.
thetamin
Minimum pitch angle (thetamin). It is type dependent parameter.
ttheta
Pitch time constant (ttheta). It is type dependent parameter.
WindGenTurbineType3IEC
Wind turbine type 3 model with which this pitch control model is associated.
No
WindContPitchAngleIEC
Wind control pitch angle model associated with this wind turbine type 3.
WindContPitchAngleIEC
Yes
WindContPType3IEC
P control model Type 3.
Reference: IEC Standard 61400-27-1 Section 6.6.5.3.
dpmax
Maximum wind turbine power ramp rate (dpmax). It is project dependent parameter.
dtrisemaxlvrt
Limitation of torque rise rate during LVRT for S1 (dTrisemaxLVRT). It is project dependent parameter.
kdtd
Gain for active drive train damping (KDTD). It is type dependent parameter.
kip
PI controller integration parameter (KIp). It is type dependent parameter.
kpp
PI controller proportional gain (KPp). It is type dependent parameter.
mplvrt
Enable LVRT power control mode (MpLVRT).
true = 1: voltage control
false = 0: reactive power control.
It is project dependent parameter.
omegaoffset
Offset to reference value that limits controller action during rotor speed changes (omegaoffset). It is case dependent parameter.
pdtdmax
Maximum active drive train damping power (pDTDmax). It is type dependent parameter.
rramp
Ramp limitation of torque, required in some grid codes (Rramp). It is project dependent parameter.
tdvs
Time delay after deep voltage sags (TDVS). It is project dependent parameter.
temin
Minimum electrical generator torque (Temin). It is type dependent parameter.
tomegafilt
Filter time constant for generator speed measurement (Tomegafilt). It is type dependent parameter.
tpfilt
Filter time constant for power measurement (Tpfilt). It is type dependent parameter.
tpord
Time constant in power order lag (Tpord). It is type dependent parameter.
tufilt
Filter time constant for voltage measurement (Tufilt). It is type dependent parameter.
tuscale
Voltage scaling factor of reset-torque (Tuscale). It is project dependent parameter.
twref
Time constant in speed reference filter (Tomega,ref). It is type dependent parameter.
udvs
Voltage limit for hold LVRT status after deep voltage sags (uDVS). It is project dependent parameter.
updip
Voltage dip threshold for P-control (uPdip). Part of turbine control, often different (e.g 0.8) from converter thresholds. It is project dependent parameter.
wdtd
Active drive train damping frequency (omegaDTD). It can be calculated from two mass model parameters. It is type dependent parameter.
zeta
Coefficient for active drive train damping (zeta). It is type dependent parameter.
WindGenTurbineType3IEC
Wind turbine type 3 model with which this Wind control P type 3 model is associated.
No
WindContPType3IEC
Wind control P type 3 model associated with this wind turbine type 3 model.
WindContPType3IEC
Yes
WindDynamicsLookupTable
The P control type 3 model with which this wind dynamics lookup table is associated.
No
WindContPType3IEC
The wind dynamics lookup table associated with this P control type 3 model.
WindContPType3IEC
Yes
WindContPType4aIEC
P control model Type 4A.
Reference: IEC Standard 61400-27-1 Section 6.6.5.4.
dpmax
Maximum wind turbine power ramp rate (dpmax). It is project dependent parameter.
tpord
Time constant in power order lag (Tpord). It is type dependent parameter.
tufilt
Voltage measurement filter time constant (Tufilt). It is type dependent parameter.
WindTurbineType4aIEC
Wind turbine type 4A model with which this wind control P type 4A model is associated.
No
WindContPType4aIEC
Wind control P type 4A model associated with this wind turbine type 4A model.
WindContPType4aIEC
Yes
WindContPType4bIEC
P control model Type 4B.
Reference: IEC Standard 61400-27-1 Section 6.6.5.5.
dpmax
Maximum wind turbine power ramp rate (dpmax). It is project dependent parameter.
tpaero
Time constant in aerodynamic power response (Tpaero). It is type dependent parameter.
tpord
Time constant in power order lag (Tpord). It is type dependent parameter.
tufilt
Voltage measurement filter time constant (Tufilt). It is type dependent parameter.
WindTurbineType4bIEC
Wind turbine type 4B model with which this wind control P type 4B model is associated.
No
WindContPType4bIEC
Wind control P type 4B model associated with this wind turbine type 4B model.
WindContPType4bIEC
Yes
WindContQIEC
Q control model.
Reference: IEC Standard 61400-27-1 Section 6.6.5.6.
iqh1
Maximum reactive current injection during dip (iqh1). It is type dependent parameter.
iqmax
Maximum reactive current injection (iqmax). It is type dependent parameter.
iqmin
Minimum reactive current injection (iqmin). It is type dependent parameter.
iqpost
Post fault reactive current injection (iqpost). It is project dependent parameter.
kiq
Reactive power PI controller integration gain (KI,q). It is type dependent parameter.
kiu
Voltage PI controller integration gain (KI,u). It is type dependent parameter.
kpq
Reactive power PI controller proportional gain (KP,q). It is type dependent parameter.
kpu
Voltage PI controller proportional gain (KP,u). It is type dependent parameter.
kqv
Voltage scaling factor for LVRT current (Kqv). It is project dependent parameter.
qmax
Maximum reactive power (qmax). It is type dependent parameter.
qmin
Minimum reactive power (qmin). It is type dependent parameter.
rdroop
Resistive component of voltage drop impedance (rdroop). It is project dependent parameter.
tiq
Time constant in reactive current lag (Tiq). It is type dependent parameter.
tpfilt
Power measurement filter time constant (Tpfilt). It is type dependent parameter.
tpost
Length of time period where post fault reactive power is injected (Tpost). It is project dependent parameter.
tqord
Time constant in reactive power order lag (Tqord). It is type dependent parameter.
tufilt
Voltage measurement filter time constant (Tufilt). It is type dependent parameter.
udb1
Voltage dead band lower limit (udb1). It is type dependent parameter.
udb2
Voltage dead band upper limit (udb2). It is type dependent parameter.
umax
Maximum voltage in voltage PI controller integral term (umax). It is type dependent parameter.
umin
Minimum voltage in voltage PI controller integral term (umin). It is type dependent parameter.
uqdip
Voltage threshold for LVRT detection in q control (uqdip). It is type dependent parameter.
uref0
User defined bias in voltage reference (uref0), used when MqG = MG,u. It is case dependent parameter.
windLVRTQcontrolModesType
Types of LVRT Q control modes (MqLVRT). It is project dependent parameter.
WindLVRTQcontrolModesKind
LVRT Q control modes MqLVRT.
mode1
Voltage dependent reactive current injection (MLVRT,1).
mode2
Reactive current injection controlled as the pre-fault value plus an additional voltage dependent reactive current injection (MLVRT,2).
mode3
Reactive current injection controlled as the pre-fault value plus an additional voltage dependent reactive current injection during fault, and as the pre-fault value plus an additional constant reactive current injection post fault (MLVRT,3).
windQcontrolModesType
Types of general wind turbine Q control modes (MqG). It is project dependent parameter.
WindQcontrolModesKind
General wind turbine Q control modes MqG.
voltage
Voltage control (MG,u).
reactivePower
Reactive power control (MG,q).
openLoopReactivePower
Open loop reactive power control (only used with closed loop at plant level) (MG,qol).
powerFactor
Power factor control (MG,pf).
xdroop
Inductive component of voltage drop impedance (xdroop). It is project dependent parameter.
WindTurbineType3or4IEC
Wind turbine type 3 or 4 model with which this reactive control mode is associated.
No
WIndContQIEC
Wind control Q model associated with this wind turbine type 3 or 4 model.
WIndContQIEC
Yes
WindContRotorRIEC
Rotor resistance control model.
Reference: IEC Standard 61400-27-1 Section 6.6.5.2.
kirr
Integral gain in rotor resistance PI controller (KIrr). It is type dependent parameter.
komegafilt
Filter gain for generator speed measurement (Komegafilt). It is type dependent parameter.
kpfilt
Filter gain for power measurement (Kpfilt). It is type dependent parameter.
kprr
Proportional gain in rotor resistance PI controller (KPrr). It is type dependent parameter.
rmax
Maximum rotor resistance (rmax). It is type dependent parameter.
rmin
Minimum rotor resistance (rmin). It is type dependent parameter.
tomegafilt
Filter time constant for generator speed measurement (Tomegafilt). It is type dependent parameter.
tpfilt
Filter time constant for power measurement (Tpfilt). It is type dependent parameter.
WindContRotorRIEC
The rotor resistance control model with which this wind dynamics lookup table is associated.
Yes
WindDynamicsLookupTable
The wind dynamics lookup table associated with this rotor resistance control model.
WindDynamicsLookupTable
No
WindGenTurbineType2IEC
Wind turbine type 2 model with whitch this wind control rotor resistance model is associated.
No
WindContRotorRIEC
Wind control rotor resistance model associated with wind turbine type 2 model.
WindContRotorRIEC
Yes
WindDynamicsLookupTable
The class models a look up table for the purpose of wind standard models.
input
Input value (x) for the lookup table function.
lookupTableFunctionType
Type of the lookup table function.
WindLookupTableFunctionKind
Function of the lookup table.
fpslip
Power versus slip lookup table (fpslip()). It is used for rotor resistance control model, IEC 61400-27-1, section 6.6.5.2.
fpomega
Power vs. speed lookup table (fpomega()). It is used for P control model type 3, IEC 61400-27-1, section 6.6.5.3.
ipvdl
Lookup table for voltage dependency of active current limits (ipVDL()). It is used for current limitation model, IEC 61400-27-1, section 6.6.5.7.
iqvdl
Lookup table for voltage dependency of reactive current limits (iqVDL()). It is used for current limitation model, IEC 61400-27-1, section 6.6.5.7.
fdpf
Power vs. frequency lookup table (fdpf()). It is used for wind power plant frequency and active power control model, IEC 61400-27-1, Annex E.
output
Output value (y) for the lookup table function.
sequence
Sequence numbers of the pairs of the input (x) and the output (y) of the lookup table function.
WindDynamicsLookupTable
The frequency and active power wind plant control model with which this wind dynamics lookup table is associated.
No
WindPlantFreqPcontrolIEC
The wind dynamics lookup table associated with this frequency and active power wind plant model.
WindPlantFreqPcontrolIEC
Yes
WindGenTurbineType1IEC
Wind turbine IEC Type 1.
Reference: IEC Standard 61400-27-1, section 6.5.2.
WindGenTurbineType2IEC
Wind turbine IEC Type 2.
Reference: IEC Standard 61400-27-1, section 6.5.3.
WindGenTurbineType2IEC
Wind turbine type 2 model with which this Pitch control emulator model is associated.
No
WindPitchContEmulIEC
Pitch control emulator model associated with this wind turbine type 2 model.
WindPitchContEmulIEC
Yes
WindGenTurbineType3aIEC
IEC Type 3A generator set model.
Reference: IEC Standard 61400-27-1 Section 6.6.3.2.
kpc
Current PI controller proportional gain (KPc). It is type dependent parameter.
xs
Electromagnetic transient reactance (xS). It is type dependent parameter.
tic
Current PI controller integration time constant (TIc). It is type dependent parameter.
WindGenTurbineType3bIEC
IEC Type 3B generator set model.
Reference: IEC Standard 61400-27-1 Section 6.6.3.3.
fducw
Crowbar duration versus voltage variation look-up table (fduCW()). It is case dependent parameter.
tg
Current generation Time constant (Tg). It is type dependent parameter.
two
Time constant for crowbar washout filter (Two). It is case dependent parameter.
mwtcwp
Crowbar control mode (MWTcwp).
- true = 1 in the model
- false = 0 in the model.
The parameter is case dependent parameter.
xs
Electromagnetic transient reactance (xS). It is type dependent parameter.
WindGenTurbineType3IEC
Generator model for wind turbines of IEC type 3A and 3B.
abstract
dipmax
Maximum active current ramp rate (dipmax). It is project dependent parameter.
diqmax
Maximum reactive current ramp rate (diqmax). It is project dependent parameter.
WindGenTurbineType3IEC
Wind turbine Type 3 model with which this wind mechanical model is associated.
No
WindMechIEC
Wind mechanical model associated with this wind turbine Type 3 model.
WindMechIEC
Yes
WindGenType4IEC
IEC Type 4 generator set model.
Reference: IEC Standard 61400-27-1 Section 6.6.3.4.
abstract
dipmax
Maximum active current ramp rate (dipmax). It is project dependent parameter.
diqmin
Minimum reactive current ramp rate (diqmin). It is case dependent parameter.
diqmax
Maximum reactive current ramp rate (diqmax). It is project dependent parameter.
tg
Time constant (Tg). It is type dependent parameter.
WindMechIEC
Two mass model.
Reference: IEC Standard 61400-27-1 Section 6.6.2.1.
cdrt
Drive train damping (cdrt). It is type dependent parameter.
hgen
Inertia constant of generator (Hgen). It is type dependent parameter.
hwtr
Inertia constant of wind turbine rotor (HWTR). It is type dependent parameter.
kdrt
Drive train stiffness (kdrt). It is type dependent parameter.
WindTurbineType4bIEC
Wind turbine type 4B model with which this wind mechanical model is associated.
No
WindMechIEC
Wind mechanical model associated with this wind turbine Type 4B model.
WindMechIEC
Yes
WindTurbineType1or2IEC
Wind generator type 1 or 2 model with which this wind mechanical model is associated.
No
WindMechIEC
Wind mechanical model associated with this wind generator type 1 or 2 model.
WindMechIEC
Yes
WindPitchContEmulIEC
Pitch control emulator model.
Reference: IEC Standard 61400-27-1 Section 6.6.5.1.
kdroop
Power error gain (Kdroop). It is case dependent parameter.
kipce
Pitch control emulator integral constant (KI,pce). It is type dependent parameter.
komegaaero
Aerodynamic power change vs. omegaWTR change (Komegaaero). It is case dependent parameter.
kppce
Pitch control emulator proportional constant (KP,pce). It is type dependent parameter.
omegaref
Rotor speed in initial steady state (omegaref). It is case dependent parameter.
pimax
Maximum steady state power (pimax). It is case dependent parameter.
pimin
Minimum steady state power (pimin). It is case dependent parameter.
t1
First time constant in pitch control lag (T1). It is type dependent parameter.
t2
Second time constant in pitch control lag (T2). It is type dependent parameter.
tpe
Time constant in generator air gap power lag (Tpe). It is type dependent parameter.
WindPlantDynamics
Parent class supporting relationships to wind turbines Type 3 and 4 and wind plant IEC and user defined wind plants including their control models.
abstract
WindTurbineType3or4Dynamics
The wind turbine type 3 or 4 associated with this wind plant.
No
WindPlantDynamics
The wind plant with which the wind turbines type 3 or 4 are associated.
WindPlantDynamics
Yes
WindPlantFreqPcontrolIEC
Frequency and active power controller model.
Reference: IEC Standard 61400-27-1 Annex E.
dprefmax
Maximum ramp rate of pWTref request from the plant controller to the wind turbines (dprefmax). It is project dependent parameter.
dprefmin
Minimum (negative) ramp rate of pWTref request from the plant controller to the wind turbines (dprefmin). It is project dependent parameter.
kiwpp
Plant P controller integral gain (KIWPp). It is type dependent parameter.
kpwpp
Plant P controller proportional gain (KPWPp). It is type dependent parameter.
prefmax
Maximum pWTref request from the plant controller to the wind turbines (prefmax). It is type dependent parameter.
prefmin
Minimum pWTref request from the plant controller to the wind turbines (prefmin). It is type dependent parameter.
tpft
Lead time constant in reference value transfer function (Tpft). It is type dependent parameter.
tpfv
Lag time constant in reference value transfer function (Tpfv). It is type dependent parameter.
twpffilt
Filter time constant for frequency measurement (TWPffilt). It is type dependent parameter.
twppfilt
Filter time constant for active power measurement (TWPpfilt). It is type dependent parameter.
WindPlantIEC
Wind plant model with which this wind plant frequency and active power control is associated.
No
WindPlantFreqPcontrolIEC
Wind plant frequency and active power control model associated with this wind plant.
WindPlantFreqPcontrolIEC
Yes
WindPlantIEC
Simplified IEC type plant level model.
Reference: IEC 61400-27-1, AnnexE.
WindPlantIEC
Wind plant model with which this wind reactive control is associated.
No
WindPlantReactiveControlIEC
Wind plant reactive control model associated with this wind plant.
WindPlantReactiveControlIEC
Yes
WindPlantReactiveControlIEC
Simplified plant voltage and reactive power control model for use with type 3 and type 4 wind turbine models.
Reference: IEC Standard 61400-27-1 Annex E.
kiwpx
Plant Q controller integral gain (KIWPx). It is type dependent parameter.
kpwpx
Plant Q controller proportional gain (KPWPx). It is type dependent parameter.
kwpqu
Plant voltage control droop (KWPqu). It is project dependent parameter.
mwppf
Power factor control modes selector (MWPpf). Used only if mwpu is set to false.
true = 1: power factor control
false = 0: reactive power control.
It is project dependent parameter.
mwpu
Reactive power control modes selector (MWPu).
true = 1: voltage control
false = 0: reactive power control.
It is project dependent parameter.
twppfilt
Filter time constant for active power measurement (TWPpfilt). It is type dependent parameter.
twpqfilt
Filter time constant for reactive power measurement (TWPqfilt). It is type dependent parameter.
twpufilt
Filter time constant for voltage measurement (TWPufilt). It is type dependent parameter.
txft
Lead time constant in reference value transfer function (Txft). It is type dependent parameter.
txfv
Lag time constant in reference value transfer function (Txfv). It is type dependent parameter.
uwpqdip
Voltage threshold for LVRT detection in q control (uWPqdip). It is type dependent parameter.
xrefmax
Maximum xWTref (qWTref or delta uWTref) request from the plant controller (xrefmax). It is project dependent parameter.
xrefmin
Minimum xWTref (qWTref or deltauWTref) request from the plant controller (xrefmin). It is project dependent parameter.
WindProtectionIEC
The grid protection model includes protection against over and under voltage, and against over and under frequency.
Reference: IEC Standard 614000-27-1 Section 6.6.6.
fover
Set of wind turbine over frequency protection levels (fover). It is project dependent parameter.
funder
Set of wind turbine under frequency protection levels (funder). It is project dependent parameter.
tfover
Set of corresponding wind turbine over frequency protection disconnection times (Tfover). It is project dependent parameter.
tfunder
Set of corresponding wind turbine under frequency protection disconnection times (Tfunder). It is project dependent parameter.
tuover
Set of corresponding wind turbine over voltage protection disconnection times (Tuover). It is project dependent parameter.
tuunder
Set of corresponding wind turbine under voltage protection disconnection times (Tuunder). It is project dependent parameter.
uover
Set of wind turbine over voltage protection levels (uover). It is project dependent parameter.
uunder
Set of wind turbine under voltage protection levels (uunder). It is project dependent parameter.
WindTurbineType3or4IEC
Wind generator type 3 or 4 model with which this wind turbine protection model is associated.
No
WindProtectionIEC
Wind turbune protection model associated with this wind generator type 3 or 4 model.
WindProtectionIEC
Yes
WindTurbineType1or2IEC
Wind generator type 1 or 2 model with which this wind turbine protection model is associated.
No
WindProtectionIEC
Wind turbune protection model associated with this wind generator type 1 or 2 model.
WindProtectionIEC
Yes
WindTurbineType1or2Dynamics
Parent class supporting relationships to wind turbines Type 1 and 2 and their control models.
abstract
WindTurbineType1or2IEC
Generator model for wind turbine of IEC Type 1 or Type 2 is a standard asynchronous generator model.
Reference: IEC Standard 614000-27-1 Section 6.6.3.1.
abstract
WindTurbineType3or4Dynamics
Parent class supporting relationships to wind turbines Type 3 and 4 and wind plant including their control models.
abstract
WindTurbineType3or4IEC
Parent class supporting relationships to IEC wind turbines Type 3 and 4 and wind plant including their control models.
abstract
WindTurbineType4aIEC
Wind turbine IEC Type 4A.
Reference: IEC Standard 61400-27-1, section 6.5.5.2.
WindTurbineType4bIEC
Wind turbine IEC Type 4A.
Reference: IEC Standard 61400-27-1, section 6.5.5.3.
LoadDynamics
Dynamic load models are used to represent the dynamic real and reactive load behaviour of a load from the static power flow model.
Dynamic load models can be defined as applying either to a single load (energy consumer) or to a group of energy consumers.
Large industrial motors or groups of similar motors may be represented by individual motor models (synchronous or asynchronous) which are usually represented as generators with negative Pgen in the static (power flow) data.
In the CIM, such individual modelling is handled by child classes of either the SynchronousMachineDynamics or AsynchronousMachineDynamics classes.
LoadComposite
This models combines static load and induction motor load effects.
The dynamics of the motor are simplified by linearizing the induction machine equations.
epvs
Active load-voltage dependence index (static) (Epvs). Typical Value = 0.7.
epfs
Active load-frequency dependence index (static) (Epfs). Typical Value = 1.5.
eqvs
Reactive load-voltage dependence index (static) (Eqvs). Typical Value = 2.
eqfs
Reactive load-frequency dependence index (static) (Eqfs). Typical Value = 0.
epvd
Active load-voltage dependence index (dynamic) (Epvd). Typical Value = 0.7.
epfd
Active load-frequency dependence index (dynamic) (Epfd). Typical Value = 1.5.
eqvd
Reactive load-voltage dependence index (dynamic) (Eqvd). Typical Value = 2.
eqfd
Reactive load-frequency dependence index (dynamic) (Eqfd). Typical Value = 0.
lfrac
Loading factor – ratio of initial P to motor MVA base (Lfrac). Typical Value = 0.8.
h
Inertia constant (H). Typical Value = 2.5.
pfrac
Fraction of constant-power load to be represented by this motor model (Pfrac) (>=0.0 and <=1.0). Typical Value = 0.5.
LoadGenericNonLinear
These load models (known also as generic non-linear dynamic (GNLD) load models) can be used in mid-term and long-term voltage stability simulations (i.e., to study voltage collapse), as they can replace a more detailed representation of aggregate load, including induction motors, thermostatically controlled and static loads.
genericNonLinearLoadModelType
Type of generic non-linear load model.
GenericNonLinearLoadModelKind
Type of generic non-linear load model.
exponentialRecovery
Exponential recovery model.
loadAdaptive
Load adaptive model.
pt
Dynamic portion of active load (PT).
qt
Dynamic portion of reactive load (QT).
tp
Time constant of lag function of active power (TP).
tq
Time constant of lag function of reactive power (TQ).
ls
Steady state voltage index for active power (LS).
lt
Transient voltage index for active power (LT).
bs
Steady state voltage index for reactive power (BS).
bt
Transient voltage index for reactive power (BT).
LoadDynamics
Load whose behaviour is described by reference to a standard model or by definition of a user-defined model.
A standard feature of dynamic load behaviour modelling is the ability to associate the same behaviour to multiple energy consumers by means of a single aggregate load definition. Aggregate loads are used to represent all or part of the real and reactive load from one or more loads in the static (power flow) data. This load is usually the aggregation of many individual load devices and the load model is approximate representation of the aggregate response of the load devices to system disturbances. The load model is always applied to individual bus loads (energy consumers) but a single set of load model parameters can used for all loads in the grouping.
abstract
LoadAggregate
Standard aggregate load model comprised of static and/or dynamic components. A static load model represents the sensitivity of the real and reactive power consumed by the load to the amplitude and frequency of the bus voltage. A dynamic load model can used to represent the aggregate response of the motor components of the load.
LoadAggregate
Aggregate load to which this aggregate static load belongs.
Yes
LoadStatic
Aggregate static load associated with this aggregate load.
LoadStatic
No
LoadAggregate
Aggregate load to which this aggregate motor (dynamic) load belongs.
Yes
LoadMotor
Aggregate motor (dynamic) load associated with this aggregate load.
LoadMotor
No
LoadStatic
General static load model representing the sensitivity of the real and reactive power consumed by the load to the amplitude and frequency of the bus voltage.
staticLoadModelType
Type of static load model. Typical Value = constantZ.
StaticLoadModelKind
Type of static load model.
exponential
Exponential P and Q equations are used and the following attributes are required:
kp1, kp2, kp3, kpf, ep1, ep2, ep3
kq1, kq2, kq3, kqf, eq1, eq2, eq3.
zIP1
ZIP1 P and Q equations are used and the following attributes are required:
kp1, kp2, kp3, kpf
kq1, kq2, kq3, kqf.
zIP2
This model separates the frequency-dependent load (primarily motors) from other load. ZIP2 P and Q equations are used and the following attributes are required:
kp1, kp2, kp3, kq4, kpf
kq1, kq2, kq3, kq4, kqf.
constantZ
The load is represented as a constant impedance. ConstantZ P and Q equations are used and no attributes are required.
kp1
First term voltage coefficient for active power (Kp1). Not used when .staticLoadModelType = constantZ.
kp2
Second term voltage coefficient for active power (Kp2). Not used when .staticLoadModelType = constantZ.
kp3
Third term voltage coefficient for active power (Kp3). Not used when .staticLoadModelType = constantZ.
kp4
Frequency coefficient for active power (Kp4). Must be non-zero when .staticLoadModelType = ZIP2. Not used for all other values of .staticLoadModelType.
ep1
First term voltage exponent for active power (Ep1). Used only when .staticLoadModelType = exponential.
ep2
Second term voltage exponent for active power (Ep2). Used only when .staticLoadModelType = exponential.
ep3
Third term voltage exponent for active power (Ep3). Used only when .staticLoadModelType = exponential.
kpf
Frequency deviation coefficient for active power (Kpf). Not used when .staticLoadModelType = constantZ.
kq1
First term voltage coefficient for reactive power (Kq1). Not used when .staticLoadModelType = constantZ.
kq2
Second term voltage coefficient for reactive power (Kq2). Not used when .staticLoadModelType = constantZ.
kq3
Third term voltage coefficient for reactive power (Kq3). Not used when .staticLoadModelType = constantZ.
kq4
Frequency coefficient for reactive power (Kq4). Must be non-zero when .staticLoadModelType = ZIP2. Not used for all other values of .staticLoadModelType.
eq1
First term voltage exponent for reactive power (Eq1). Used only when .staticLoadModelType = exponential.
eq2
Second term voltage exponent for reactive power (Eq2). Used only when .staticLoadModelType = exponential.
eq3
Third term voltage exponent for reactive power (Eq3). Used only when .staticLoadModelType = exponential.
kqf
Frequency deviation coefficient for reactive power (Kqf). Not used when .staticLoadModelType = constantZ.
LoadMotor
Aggregate induction motor load. This model is used to represent a fraction of an ordinary load as "induction motor load". It allows load that is treated as ordinary constant power in power flow analysis to be represented by an induction motor in dynamic simulation. If Lpp = 0. or Lpp = Lp, or Tppo = 0., only one cage is represented. Magnetic saturation is not modelled. Either a "one-cage" or "two-cage" model of the induction machine can be modelled. Magnetic saturation is not modelled.
This model is intended for representation of aggregations of many motors dispersed through a load represented at a high voltage bus but where there is no information on the characteristics of individual motors.
This model treats a fraction of the constant power part of a load as a motor. During initialisation, the initial power drawn by the motor is set equal to Pfrac times the constant P part of the static load. The remainder of the load is left as static load.
The reactive power demand of the motor is calculated during initialisation as a function of voltage at the load bus. This reactive power demand may be less than or greater than the constant Q component of the load. If the motor's reactive demand is greater than the constant Q component of the load, the model inserts a shunt capacitor at the terminal of the motor to bring its reactive demand down to equal the constant Q reactive load.
If a motor model and a static load model are both present for a load, the motor Pfrac is assumed to be subtracted from the power flow constant P load before the static load model is applied. The remainder of the load, if any, is then represented by the static load model.
pfrac
Fraction of constant-power load to be represented by this motor model (Pfrac) (>=0.0 and <=1.0). Typical Value = 0.3.
lfac
Loading factor – ratio of initial P to motor MVA base (Lfac). Typical Value = 0.8.
ls
Synchronous reactance (Ls). Typical Value = 3.2.
lp
Transient reactance (Lp). Typical Value = 0.15.
lpp
Subtransient reactance (Lpp). Typical Value = 0.15.
ra
Stator resistance (Ra). Typical Value = 0.
tpo
Transient rotor time constant (Tpo) (not=0). Typical Value = 1.
tppo
Subtransient rotor time constant (Tppo). Typical Value = 0.02.
h
Inertia constant (H) (not=0). Typical Value = 0.4.
d
Damping factor (D). Unit = delta P/delta speed. Typical Value = 2.
vt
Voltage threshold for tripping (Vt). Typical Value = 0.7.
tv
Voltage trip pickup time (Tv). Typical Value = 0.1.
tbkr
Circuit breaker operating time (Tbkr). Typical Value = 0.08.
PK ! A W cimpyorm/res/schemata/CIM16/EquipmentBoundaryProfileRDFSAugmented-v2_4_15-16Feb2016.rdf
EquipmentBoundaryProfile
This profile has been built on the basis of the IEC 61970-452 document and adjusted to fit the purpose of the ENTSO-E boundary profile.
EquipmentBoundaryVersion
Profile version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURIcore
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentBoundary/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIoperation
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentBoundaryOperation/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
Core
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
ConductingEquipment
The conducting equipment of the terminal. Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
Yes
Terminals
Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
Terminals
No
ConnectivityNode
Connectivity nodes are points where terminals of AC conducting equipment are connected together with zero impedance.
Operation
boundaryPoint
Entsoe
Identifies if a node is a BoundaryPoint. If boundaryPoint=true the ConnectivityNode or the TopologicalNode represents a BoundaryPoint.
Boolean
A type with the value space "true" and "false".
Primitive
fromEndIsoCode
Entsoe
The attribute is used for an exchange of the ISO code of the region to which the “From” side of the Boundary point belongs to or it is connected to.
The ISO code is two characters country code as defined by ISO 3166 (
http://www.iso.org/iso/country_codes
). The length of the string is 2 characters maximum.
The attribute is a required for the Boundary Model Authority Set where this attribute is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
fromEndName
Entsoe
The attribute is used for an exchange of a human readable name with length of the string 32 characters maximum. The attribute covers two cases:
- if the Boundary point is placed on a tie-line the attribute is used for exchange of the geographical name of the substation to which the “From” side of the tie-line is connected to.
- if the Boundary point is placed in a substation the attribute is used for exchange of the name of the element (e.g. PowerTransformer, ACLineSegment, Switch, etc) to which the “From” side of the Boundary point is connected to.
The attribute is required for the Boundary Model Authority Set where it is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
fromEndNameTso
Entsoe
The attribute is used for an exchange of the name of the TSO to which the “From” side of the Boundary point belongs to or it is connected to. The length of the string is 32 characters maximum.
The attribute is required for the Boundary Model Authority Set where it is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
toEndIsoCode
Entsoe
The attribute is used for an exchange of the ISO code of the region to which the “To” side of the Boundary point belongs to or it is connected to.
The ISO code is two characters country code as defined by ISO 3166 (
http://www.iso.org/iso/country_codes
). The length of the string is 2 characters maximum.
The attribute is a required for the Boundary Model Authority Set where this attribute is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
toEndName
Entsoe
The attribute is used for an exchange of a human readable name with length of the string 32 characters maximum. The attribute covers two cases:
- if the Boundary point is placed on a tie-line the attribute is used for exchange of the geographical name of the substation to which the “To” side of the tie-line is connected to.
- if the Boundary point is placed in a substation the attribute is used for exchange of the name of the element (e.g. PowerTransformer, ACLineSegment, Switch, etc) to which the “To” side of the Boundary point is connected to.
The attribute is required for the Boundary Model Authority Set where it is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
toEndNameTso
Entsoe
The attribute is used for an exchange of the name of the TSO to which the “To” side of the Boundary point belongs to or it is connected to. The length of the string is 32 characters maximum.
The attribute is required for the Boundary Model Authority Set where it is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
ConnectivityNodeContainer
Container of this connectivity node.
Yes
ConnectivityNodes
Connectivity nodes which belong to this connectivity node container.
ConnectivityNodes
No
ConnectivityNodeContainer
A base class for all objects that may contain connectivity nodes or topological nodes.
Equipment
The parts of a power system that are physical devices, electronic or mechanical.
EquipmentContainer
Container of this equipment.
Yes
Equipments
Contained equipment.
Equipments
No
EquipmentContainer
A modeling construct to provide a root class for containing equipment.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
BaseVoltage
Defines a system base voltage which is referenced.
nominalVoltage
The power system resource's base voltage.
Voltage
Electrical voltage, can be both AC and DC.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
GeographicalRegion
A geographical region of a power system network model.
Regions
All sub-geograhpical regions within this geographical region.
No
Region
The geographical region to which this sub-geographical region is within.
Region
Yes
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
energyIdentCodeEic
Entsoe
The attribute is used for an exchange of the EIC code (Energy identification Code). The length of the string is 16 characters as defined by the EIC code.
References:
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
shortName
Entsoe
The attribute is used for an exchange of a human readable short name with length of the string 12 characters maximum.
SubGeographicalRegion
A subset of a geographical region of a power system network model.
Region
The lines within the sub-geographical region.
Yes
Lines
The sub-geographical region of the line.
Lines
No
Wires
Connector
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation and are modelled with a single logical terminal.
EnergySchedulingType
Used to define the type of generation for scheduling purposes.
Entsoe
EnergySource
Energy Source of a particular Energy Scheduling Type
No
EnergySchedulingType
Energy Scheduling Type of an Energy Source
EnergySchedulingType
Yes
EnergySource
A generic equivalent for an energy supplier on a transmission or distribution voltage level.
Junction
A point where one or more conducting equipments are connected with zero resistance.
Line
Contains equipment beyond a substation belonging to a power transmission line.
PK ! iV V [ cimpyorm/res/schemata/CIM16/EquipmentProfileCoreOperationRDFSAugmented-v2_4_15-4Jul2016.rdf
EquipmentProfile
This profile has been built on the basis of the IEC 61970-452 document and adjusted to fit the purpose of the ENTSO-E CGMES.
EquipmentVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURIcore
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
baseURIoperation
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
baseURIshortCircuit
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURIcore
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentCore/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIoperation
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentOperation/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIshortCircuit
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentShortCircuit/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
DC
ACDCConverter
A unit with valves for three phases, together with unit control equipment, essential protective and switching devices, DC storage capacitors, phase reactors and auxiliaries, if any, used for conversion.
baseS
Base apparent power of the converter pole.
ApparentPower
Product of the RMS value of the voltage and the RMS value of the current.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
idleLoss
Active power loss in pole at no power transfer. Converter configuration data used in power flow.
ActivePower
Product of RMS value of the voltage and the RMS value of the in-phase component of the current.
CIMDatatype
value
unit
multiplier
maxUdc
The maximum voltage on the DC side at which the converter should operate. Converter configuration data used in power flow.
Voltage
Electrical voltage, can be both AC and DC.
CIMDatatype
value
unit
multiplier
minUdc
Min allowed converter DC voltage. Converter configuration data used in power flow.
numberOfValves
Number of valves in the converter. Used in loss calculations.
Integer
An integer number. The range is unspecified and not limited.
Primitive
ratedUdc
Rated converter DC voltage, also called UdN. Converter configuration data used in power flow.
resistiveLoss
Converter configuration data used in power flow. Refer to poleLossP.
Resistance
Resistance (real part of impedance).
CIMDatatype
value
unit
multiplier
switchingLoss
Switching losses, relative to the base apparent power 'baseS'.
Refer to poleLossP.
ActivePowerPerCurrentFlow
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
valveU0
Valve threshold voltage. Forward voltage drop when the valve is conducting. Used in loss calculations, i.e. the switchLoss depend on numberOfValves * valveU0.
ACDCConverterDCTerminal
A DC electrical connection point at the AC/DC converter. The AC/DC converter is electrically connected also to the AC side. The AC connection is inherited from the AC conducting equipment in the same way as any other AC equipment. The AC/DC converter DC terminal is separate from generic DC terminal to restrict the connection with the AC side to AC/DC converter and so that no other DC conducting equipment can be connected to the AC side.
polarity
Represents the normal network polarity condition.
DCPolarityKind
Polarity for DC circuits.
positive
Positive pole.
middle
Middle pole, potentially grounded.
negative
Negative pole.
CsConverter
DC side of the current source converter (CSC).
maxAlpha
Maximum firing angle. CSC configuration data used in power flow.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
multiplier
maxGamma
Maximum extinction angle. CSC configuration data used in power flow.
maxIdc
The maximum direct current (Id) on the DC side at which the converter should operate. Converter configuration data use in power flow.
CurrentFlow
Electrical current with sign convention: positive flow is out of the conducting equipment into the connectivity node. Can be both AC and DC.
CIMDatatype
value
unit
multiplier
minAlpha
Minimum firing angle. CSC configuration data used in power flow.
minGamma
Minimum extinction angle. CSC configuration data used in power flow.
minIdc
The minimum direct current (Id) on the DC side at which the converter should operate. CSC configuration data used in power flow.
ratedIdc
Rated converter DC current, also called IdN. Converter configuration data used in power flow.
DCBaseTerminal
An electrical connection point at a piece of DC conducting equipment. DC terminals are connected at one physical DC node that may have multiple DC terminals connected. A DC node is similar to an AC connectivity node. The model enforces that DC connections are distinct from AC connections.
DCBreaker
A breaker within a DC system.
DCBusbar
A busbar within a DC system.
DCChopper
Low resistance equipment used in the internal DC circuit to balance voltages. It has typically positive and negative pole terminals and a ground.
DCConductingEquipment
The parts of the DC power system that are designed to carry current or that are conductively connected through DC terminals.
DCConverterOperatingModeKind
The operating mode of an HVDC bipole.
bipolar
Bipolar operation.
monopolarMetallicReturn
Monopolar operation with metallic return
monopolarGroundReturn
Monopolar operation with ground return
DCConverterUnit
Indivisible operative unit comprising all equipment between the point of common coupling on the AC side and the point of common coupling – DC side, essentially one or more converters, together with one or more converter transformers, converter control equipment, essential protective and switching devices and auxiliaries, if any, used for conversion.
operationMode
DCDisconnector
A disconnector within a DC system.
DCEquipmentContainer
A modeling construct to provide a root class for containment of DC as well as AC equipment. The class differ from the EquipmentContaner for AC in that it may also contain DCNodes. Hence it can contain both AC and DC equipment.
DCGround
A ground within a DC system.
inductance
Inductance to ground.
Inductance
Inductive part of reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
r
Resistance to ground.
DCLine
Overhead lines and/or cables connecting two or more HVDC substations.
DCLineSegment
A wire or combination of wires not insulated from one another, with consistent electrical characteristics, used to carry direct current between points in the DC region of the power system.
capacitance
Capacitance of the DC line segment. Significant for cables only.
Capacitance
Capacitive part of reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
inductance
Inductance of the DC line segment. Neglectable compared with DCSeriesDevice used for smoothing.
resistance
Resistance of the DC line segment.
length
Segment length for calculating line section capabilities.
Length
Unit of length. Never negative.
CIMDatatype
value
unit
multiplier
DCNode
DC nodes are points where terminals of DC conducting equipment are connected together with zero impedance.
DCSeriesDevice
A series device within the DC system, typically a reactor used for filtering or smoothing. Needed for transient and short circuit studies.
inductance
Inductance of the device.
resistance
Resistance of the DC device.
ratedUdc
Rated DC device voltage. Converter configuration data used in power flow.
DCShunt
A shunt device within the DC system, typically used for filtering. Needed for transient and short circuit studies.
capacitance
Capacitance of the DC shunt.
resistance
Resistance of the DC device.
ratedUdc
Rated DC device voltage. Converter configuration data used in power flow.
DCSwitch
A switch within the DC system.
DCTerminal
An electrical connection point to generic DC conducting equipment.
PerLengthDCLineParameter
capacitance
Capacitance per unit of length of the DC line segment; significant for cables only.
CapacitancePerLength
Capacitance per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
inductance
Inductance per unit of length of the DC line segment.
InductancePerLength
Inductance per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
resistance
Resistance per length of the DC line segment.
ResistancePerLength
Resistance (real part of impedance) per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
VsCapabilityCurve
The P-Q capability curve for a voltage source converter, with P on x-axis and Qmin and Qmax on y1-axis and y2-axis.
VsConverter
DC side of the voltage source converter (VSC).
maxModulationIndex
The max quotient between the AC converter voltage (Uc) and DC voltage (Ud). A factor typically less than 1. VSC configuration data used in power flow.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
maxValveCurrent
The maximum current through a valve. This current limit is the basis for calculating the capability diagram. VSC configuration data.
Topology
BusNameMarker
Used to apply user standard names to topology buses. Typically used for "bus/branch" case generation. Associated with one or more terminals that are normally connected with the bus name. The associated terminals are normally connected by non-retained switches. For a ring bus station configuration, all busbar terminals in the ring are typically associated. For a breaker and a half scheme, both busbars would normally be associated. For a ring bus, all busbars would normally be associated. For a "straight" busbar configuration, normally only the main terminal at the busbar would be associated.
priority
Priority of bus name marker for use as topology bus name. Use 0 for don t care. Use 1 for highest priority. Use 2 as priority is less than 1 and so on.
Meas
Accumulator
Accumulator represents an accumulated (counted) Measurement, e.g. an energy value.
Operation
Measurements
A measurement may have zero or more limit ranges defined for it.
Yes
LimitSets
The Measurements using the LimitSet.
No
Accumulator
The values connected to this measurement.
Yes
AccumulatorValues
Measurement to which this value is connected.
No
AccumulatorLimit
Limit values for Accumulator measurements.
Operation
value
The value to supervise against. The value is positive.
LimitSet
The limit values used for supervision of Measurements.
Yes
Limits
The set of limits.
No
AccumulatorLimitSet
An AccumulatorLimitSet specifies a set of Limits that are associated with an Accumulator measurement.
Operation
AccumulatorReset
This command reset the counter value to zero.
Operation
AccumulatorValue
The accumulator value that is reset by the command.
Yes
AccumulatorReset
The command that reset the accumulator value.
No
AccumulatorValue
AccumulatorValue represents an accumulated (counted) MeasurementValue.
Operation
value
The value to supervise. The value is positive.
Analog
Analog represents an analog Measurement.
Operation
positiveFlowIn
If true then this measurement is an active power, reactive power or current with the convention that a positive value measured at the Terminal means power is flowing into the related PowerSystemResource.
Boolean
A type with the value space "true" and "false".
Primitive
Analog
The values connected to this measurement.
Yes
AnalogValues
Measurement to which this value is connected.
No
Measurements
A measurement may have zero or more limit ranges defined for it.
Yes
LimitSets
The Measurements using the LimitSet.
No
AnalogControl
An analog control used for supervisory control.
Operation
maxValue
Normal value range maximum for any of the Control.value. Used for scaling, e.g. in bar graphs.
minValue
Normal value range minimum for any of the Control.value. Used for scaling, e.g. in bar graphs.
AnalogValue
The Control variable associated with the MeasurementValue.
Yes
AnalogControl
The MeasurementValue that is controlled.
No
AnalogLimit
Limit values for Analog measurements.
Operation
value
The value to supervise against.
LimitSet
The limit values used for supervision of Measurements.
Yes
Limits
The set of limits.
No
AnalogLimitSet
An AnalogLimitSet specifies a set of Limits that are associated with an Analog measurement.
Operation
AnalogValue
AnalogValue represents an analog MeasurementValue.
Operation
value
The value to supervise.
Command
A Command is a discrete control used for supervisory control.
Operation
normalValue
Normal value for Control.value e.g. used for percentage scaling.
value
The value representing the actuator output.
DiscreteValue
The Control variable associated with the MeasurementValue.
Yes
Command
The MeasurementValue that is controlled.
No
ValueAliasSet
The ValueAliasSet used for translation of a Control value to a name.
Yes
Commands
The Commands using the set for translation.
No
Control
Control is used for supervisory/device control. It represents control outputs that are used to change the state in a process, e.g. close or open breaker, a set point value or a raise lower command.
Operation
controlType
Specifies the type of Control, e.g. BreakerOn/Off, GeneratorVoltageSetPoint, TieLineFlow etc. The ControlType.name shall be unique among all specified types and describe the type.
operationInProgress
Indicates that a client is currently sending control commands that has not completed.
timeStamp
The last time a control output was sent.
DateTime
Date and time as "yyyy-mm-ddThh:mm:ss.sss", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddThh:mm:ss.sssZ". A local timezone relative UTC is specified as "yyyy-mm-ddThh:mm:ss.sss-hh:mm". The second component (shown here as "ss.sss") could have any number of digits in its fractional part to allow any kind of precision beyond seconds.
Primitive
unitMultiplier
The unit multiplier of the controlled quantity.
unitSymbol
The unit of measure of the controlled quantity.
PowerSystemResource
The controller outputs used to actually govern a regulating device, e.g. the magnetization of a synchronous machine or capacitor bank breaker actuator.
Yes
Controls
Regulating device governed by this control output.
No
Discrete
Discrete represents a discrete Measurement, i.e. a Measurement representing discrete values, e.g. a Breaker position.
Operation
Discrete
The values connected to this measurement.
Yes
DiscreteValues
Measurement to which this value is connected.
No
Discretes
The Measurements using the set for translation.
No
ValueAliasSet
The ValueAliasSet used for translation of a MeasurementValue.value to a name.
Yes
DiscreteValue
DiscreteValue represents a discrete MeasurementValue.
Operation
value
The value to supervise.
Limit
Specifies one limit value for a Measurement. A Measurement typically has several limits that are kept together by the LimitSet class. The actual meaning and use of a Limit instance (i.e., if it is an alarm or warning limit or if it is a high or low limit) is not captured in the Limit class. However the name of a Limit instance may indicate both meaning and use.
Operation
LimitSet
Specifies a set of Limits that are associated with a Measurement. A Measurement may have several LimitSets corresponding to seasonal or other changing conditions. The condition is captured in the name and description attributes. The same LimitSet may be used for several Measurements. In particular percentage limits are used this way.
Operation
isPercentageLimits
Tells if the limit values are in percentage of normalValue or the specified Unit for Measurements and Controls.
Measurement
A Measurement represents any measured, calculated or non-measured non-calculated quantity. Any piece of equipment may contain Measurements, e.g. a substation may have temperature measurements and door open indications, a transformer may have oil temperature and tank pressure measurements, a bay may contain a number of power flow measurements and a Breaker may contain a switch status measurement.
The PSR - Measurement association is intended to capture this use of Measurement and is included in the naming hierarchy based on EquipmentContainer. The naming hierarchy typically has Measurements as leafs, e.g. Substation-VoltageLevel-Bay-Switch-Measurement.
Some Measurements represent quantities related to a particular sensor location in the network, e.g. a voltage transformer (PT) at a busbar or a current transformer (CT) at the bar between a breaker and an isolator. The sensing position is not captured in the PSR - Measurement association. Instead it is captured by the Measurement - Terminal association that is used to define the sensing location in the network topology. The location is defined by the connection of the Terminal to ConductingEquipment.
If both a Terminal and PSR are associated, and the PSR is of type ConductingEquipment, the associated Terminal should belong to that ConductingEquipment instance.
When the sensor location is needed both Measurement-PSR and Measurement-Terminal are used. The Measurement-Terminal association is never used alone.
Operation
measurementType
Specifies the type of measurement. For example, this specifies if the measurement represents an indoor temperature, outdoor temperature, bus voltage, line flow, etc.
phases
Indicates to which phases the measurement applies and avoids the need to use 'measurementType' to also encode phase information (which would explode the types). The phase information in Measurement, along with 'measurementType' and 'phases' uniquely defines a Measurement for a device, based on normal network phase. Their meaning will not change when the computed energizing phasing is changed due to jumpers or other reasons.
If the attribute is missing three phases (ABC) shall be assumed.
PhaseCode
Enumeration of phase identifiers. Allows designation of phases for both transmission and distribution equipment, circuits and loads.
Residential and small commercial loads are often served from single-phase, or split-phase, secondary circuits. For example of s12N, phases 1 and 2 refer to hot wires that are 180 degrees out of phase, while N refers to the neutral wire. Through single-phase transformer connections, these secondary circuits may be served from one or two of the primary phases A, B, and C. For three-phase loads, use the A, B, C phase codes instead of s12N.
ABCN
Phases A, B, C, and N.
ABC
Phases A, B, and C.
ABN
Phases A, B, and neutral.
ACN
Phases A, C and neutral.
BCN
Phases B, C, and neutral.
AB
Phases A and B.
AC
Phases A and C.
BC
Phases B and C.
AN
Phases A and neutral.
BN
Phases B and neutral.
CN
Phases C and neutral.
A
Phase A.
B
Phase B.
C
Phase C.
N
Neutral phase.
s1N
Secondary phase 1 and neutral.
s2N
Secondary phase 2 and neutral.
s12N
Secondary phases 1, 2, and neutral.
s1
Secondary phase 1.
s2
Secondary phase 2.
s12
Secondary phase 1 and 2.
unitSymbol
The unit of measure of the measured quantity.
unitMultiplier
The unit multiplier of the measured quantity.
Terminal
One or more measurements may be associated with a terminal in the network.
Yes
Measurements
Measurements associated with this terminal defining where the measurement is placed in the network topology. It may be used, for instance, to capture the sensor position, such as a voltage transformer (PT) at a busbar or a current transformer (CT) at the bar between a breaker and an isolator.
No
PowerSystemResource
The measurements associated with this power system resource.
Yes
Measurements
The power system resource that contains the measurement.
No
MeasurementValue
The current state for a measurement. A state value is an instance of a measurement from a specific source. Measurements can be associated with many state values, each representing a different source for the measurement.
Operation
timeStamp
The time when the value was last updated
sensorAccuracy
The limit, expressed as a percentage of the sensor maximum, that errors will not exceed when the sensor is used under reference conditions.
PerCent
Percentage on a defined base. For example, specify as 100 to indicate at the defined base.
CIMDatatype
value
Normally 0 - 100 on a defined base
unit
multiplier
MeasurementValue
A MeasurementValue has a MeasurementValueQuality associated with it.
Yes
MeasurementValueQuality
A MeasurementValue has a MeasurementValueQuality associated with it.
No
MeasurementValueSource
The MeasurementValues updated by the source.
Yes
MeasurementValues
A reference to the type of source that updates the MeasurementValue, e.g. SCADA, CCLink, manual, etc. User conventions for the names of sources are contained in the introduction to IEC 61970-301.
No
MeasurementValueQuality
Measurement quality flags. Bits 0-10 are defined for substation automation in draft IEC 61850 part 7-3. Bits 11-15 are reserved for future expansion by that document. Bits 16-31 are reserved for EMS applications.
Operation
MeasurementValueSource
MeasurementValueSource describes the alternative sources updating a MeasurementValue. User conventions for how to use the MeasurementValueSource attributes are described in the introduction to IEC 61970-301.
Operation
Quality61850
Quality flags in this class are as defined in IEC 61850, except for estimatorReplaced, which has been included in this class for convenience.
Operation
badReference
Measurement value may be incorrect due to a reference being out of calibration.
estimatorReplaced
Value has been replaced by State Estimator. estimatorReplaced is not an IEC61850 quality bit but has been put in this class for convenience.
failure
This identifier indicates that a supervision function has detected an internal or external failure, e.g. communication failure.
oldData
Measurement value is old and possibly invalid, as it has not been successfully updated during a specified time interval.
operatorBlocked
Measurement value is blocked and hence unavailable for transmission.
oscillatory
To prevent some overload of the communication it is sensible to detect and suppress oscillating (fast changing) binary inputs. If a signal changes in a defined time (tosc) twice in the same direction (from 0 to 1 or from 1 to 0) then oscillation is detected and the detail quality identifier "oscillatory" is set. If it is detected a configured numbers of transient changes could be passed by. In this time the validity status "questionable" is set. If after this defined numbers of changes the signal is still in the oscillating state the value shall be set either to the opposite state of the previous stable value or to a defined default value. In this case the validity status "questionable" is reset and "invalid" is set as long as the signal is oscillating. If it is configured such that no transient changes should be passed by then the validity status "invalid" is set immediately in addition to the detail quality identifier "oscillatory" (used for status information only).
outOfRange
Measurement value is beyond a predefined range of value.
overFlow
Measurement value is beyond the capability of being represented properly. For example, a counter value overflows from maximum count back to a value of zero.
source
Source gives information related to the origin of a value. The value may be acquired from the process, defaulted or substituted.
Source
Source gives information related to the origin of a value.
PROCESS
The value is provided by input from the process I/O or being calculated from some function.
DEFAULTED
The value contains a default value.
SUBSTITUTED
The value is provided by input of an operator or by an automatic source.
suspect
A correlation function has detected that the value is not consitent with other values. Typically set by a network State Estimator.
test
Measurement value is transmitted for test purposes.
validity
Validity of the measurement value.
Validity
Validity for MeasurementValue.
GOOD
The value is marked good if no abnormal condition of the acquisition function or the information source is detected.
QUESTIONABLE
The value is marked questionable if a supervision function detects an abnormal behaviour, however the value could still be valid. The client is responsible for determining whether or not values marked "questionable" should be used.
INVALID
The value is marked invalid when a supervision function recognises abnormal conditions of the acquisition function or the information source (missing or non-operating updating devices). The value is not defined under this condition. The mark invalid is used to indicate to the client that the value may be incorrect and shall not be used.
RaiseLowerCommand
An analog control that increase or decrease a set point value with pulses.
Operation
ValueAliasSet
The ValueAliasSet used for translation of a Control value to a name.
Yes
RaiseLowerCommands
The Commands using the set for translation.
No
SetPoint
An analog control that issue a set point value.
Operation
normalValue
Normal value for Control.value e.g. used for percentage scaling.
value
The value representing the actuator output.
StringMeasurement
StringMeasurement represents a measurement with values of type string.
Operation
StringMeasurement
Measurement to which this value is connected.
Yes
StringMeasurementValues
The values connected to this measurement.
No
StringMeasurementValue
StringMeasurementValue represents a measurement value of type string.
Operation
value
The value to supervise.
ValueAliasSet
Describes the translation of a set of values into a name and is intendend to facilitate cusom translations. Each ValueAliasSet has a name, description etc. A specific Measurement may represent a discrete state like Open, Closed, Intermediate etc. This requires a translation from the MeasurementValue.value number to a string, e.g. 0->"Invalid", 1->"Open", 2->"Closed", 3->"Intermediate". Each ValueToAlias member in ValueAliasSet.Value describe a mapping for one particular value to a name.
Operation
ValueAliasSet
The ValueToAlias mappings included in the set.
Yes
Values
The ValueAliasSet having the ValueToAlias mappings.
No
ValueToAlias
Describes the translation of one particular value into a name, e.g. 1 as "Open".
Operation
value
The value that is mapped.
Production
The production package is responsible for classes which describe various kinds of generators. These classes also provide production costing information which is used to economically allocate demand among committed units and calculate reserve quantities.
EnergySchedulingType
Used to define the type of generation for scheduling purposes.
Entsoe
EnergySource
A generic equivalent for an energy supplier on a transmission or distribution voltage level.
nominalVoltage
Phase-to-phase nominal voltage.
r
Positive sequence Thevenin resistance.
r0
Zero sequence Thevenin resistance.
rn
Negative sequence Thevenin resistance.
voltageAngle
Phase angle of a-phase open circuit.
AngleRadians
Phase angle in radians.
CIMDatatype
value
unit
multiplier
voltageMagnitude
Phase-to-phase open circuit voltage magnitude.
x
Positive sequence Thevenin reactance.
Reactance
Reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
x0
Zero sequence Thevenin reactance.
xn
Negative sequence Thevenin reactance.
FossilFuel
The fossil fuel consumed by the non-nuclear thermal generating unit. For example, coal, oil, gas, etc. This a the specific fuels that the generating unit can consume.
fossilFuelType
The type of fossil fuel, such as coal, oil, or gas.
FuelType
Type of fuel.
coal
Generic coal, not including lignite type.
oil
Oil.
gas
Natural gas.
lignite
The fuel is lignite coal. Note that this is a special type of coal, so the other enum of coal is reserved for hard coal types or if the exact type of coal is not known.
hardCoal
Hard coal
oilShale
Oil Shale
GeneratingUnit
A single or set of synchronous machines for converting mechanical power into alternating-current power. For example, individual machines within a set may be defined for scheduling purposes while a single control signal is derived for the set. In this case there would be a GeneratingUnit for each member of the set and an additional GeneratingUnit corresponding to the set.
genControlSource
The source of controls for a generating unit.
GeneratorControlSource
The source of controls for a generating unit.
unavailable
Not available.
offAGC
Off of automatic generation control (AGC).
onAGC
On automatic generation control (AGC).
plantControl
Plant is controlling.
governorSCD
Governor Speed Changer Droop. This is the change in generator power output divided by the change in frequency normalized by the nominal power of the generator and the nominal frequency and expressed in percent and negated. A positive value of speed change droop provides additional generator output upon a drop in frequency.
initialP
Default initial active power which is used to store a powerflow result for the initial active power for this unit in this network configuration.
longPF
Generating unit long term economic participation factor.
maximumAllowableSpinningReserve
Maximum allowable spinning reserve. Spinning reserve will never be considered greater than this value regardless of the current operating point.
maxOperatingP
This is the maximum operating active power limit the dispatcher can enter for this unit.
minOperatingP
This is the minimum operating active power limit the dispatcher can enter for this unit.
nominalP
The nominal power of the generating unit. Used to give precise meaning to percentage based attributes such as the governor speed change droop (governorSCD attribute).
The attribute shall be a positive value equal or less than RotatingMachine.ratedS.
ratedGrossMaxP
The unit's gross rated maximum capacity (book value).
ratedGrossMinP
The gross rated minimum generation level which the unit can safely operate at while delivering power to the transmission grid.
ratedNetMaxP
The net rated maximum capacity determined by subtracting the auxiliary power used to operate the internal plant machinery from the rated gross maximum capacity.
shortPF
Generating unit short term economic participation factor.
startupCost
The initial startup cost incurred for each start of the GeneratingUnit.
Money
Amount of money.
CIMDatatype
unit
Currency
Monetary currencies. Apologies for this list not being exhaustive.
USD
US dollar
EUR
European euro
AUD
Australian dollar
CAD
Canadian dollar
CHF
Swiss francs
CNY
Chinese yuan renminbi
DKK
Danish crown
GBP
British pound
JPY
Japanese yen
NOK
Norwegian crown
RUR
Russian ruble
SEK
Swedish crown
INR
India rupees
other
Another type of currency.
multiplier
value
Decimal
Decimal is the base-10 notational system for representing real numbers.
Primitive
variableCost
The variable cost component of production per unit of ActivePower.
totalEfficiency
The efficiency of the unit in converting the fuel into electrical energy.
GeneratingUnit
A generating unit may have a gross active power to net active power curve, describing the losses and auxiliary power requirements of the unit.
Yes
GrossToNetActivePowerCurves
A generating unit may have a gross active power to net active power curve, describing the losses and auxiliary power requirements of the unit.
No
GrossToNetActivePowerCurve
Relationship between the generating unit's gross active power output on the X-axis (measured at the terminals of the machine(s)) and the generating unit's net active power output on the Y-axis (based on utility-defined measurements at the power station). Station service loads, when modeled, should be treated as non-conforming bus loads. There may be more than one curve, depending on the auxiliary equipment that is in service.
Operation
HydroEnergyConversionKind
Specifies the capability of the hydro generating unit to convert energy as a generator or pump.
generator
Able to generate power, but not able to pump water for energy storage.
pumpAndGenerator
Able to both generate power and pump water for energy storage.
HydroGeneratingUnit
A generating unit whose prime mover is a hydraulic turbine (e.g., Francis, Pelton, Kaplan).
energyConversionCapability
Energy conversion capability for generating.
HydroPlantStorageKind
The type of hydro power plant.
runOfRiver
Run of river.
pumpedStorage
Pumped storage.
storage
Storage.
HydroPowerPlant
A hydro power station which can generate or pump. When generating, the generator turbines receive water from an upper reservoir. When pumping, the pumps receive their water from a lower reservoir.
hydroPlantStorageType
The type of hydro power plant water storage.
HydroPump
A synchronous motor-driven pump, typically associated with a pumped storage plant.
NuclearGeneratingUnit
A nuclear generating unit.
SolarGeneratingUnit
A solar thermal generating unit.
ThermalGeneratingUnit
A generating unit whose prime mover could be a steam turbine, combustion turbine, or diesel engine.
WindGeneratingUnit
A wind driven generating unit. May be used to represent a single turbine or an aggregation.
windGenUnitType
The kind of wind generating unit
WindGenUnitKind
Kind of wind generating unit.
offshore
The wind generating unit is located offshore.
onshore
The wind generating unit is located onshore.
Core
Contains the core PowerSystemResource and ConductingEquipment entities shared by all applications plus common collections of those entities. Not all applications require all the Core entities. This package does not depend on any other package except the Domain package, but most of the other packages have associations and generalizations that depend on it.
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
sequenceNumber
The orientation of the terminal connections for a multiple terminal conducting equipment. The sequence numbering starts with 1 and additional terminals should follow in increasing order. The first terminal is the "starting point" for a two terminal branch.
BaseVoltage
Defines a system base voltage which is referenced.
nominalVoltage
The power system resource's base voltage.
BasicIntervalSchedule
Schedule of values at points in time.
startTime
The time for the first time point.
value1Unit
Value1 units of measure.
value2Unit
Value2 units of measure.
Bay
A collection of power system resources (within a given substation) including conducting equipment, protection relays, measurements, and telemetry. A bay typically represents a physical grouping related to modularization of equipment.
Operation
Bays
The bays within this voltage level.
No
VoltageLevel
The voltage level containing this bay.
Yes
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
ConnectivityNode
Connectivity nodes are points where terminals of AC conducting equipment are connected together with zero impedance.
Operation
Terminals
The connectivity node to which this terminal connects with zero impedance.
No
ConnectivityNode
Terminals interconnected with zero impedance at a this connectivity node.
Yes
ConnectivityNodeContainer
Container of this connectivity node.
Yes
ConnectivityNodes
Connectivity nodes which belong to this connectivity node container.
No
ConnectivityNodeContainer
A base class for all objects that may contain connectivity nodes or topological nodes.
Curve
A multi-purpose curve or functional relationship between an independent variable (X-axis) and dependent (Y-axis) variables.
curveStyle
The style or shape of the curve.
CurveStyle
Style or shape of curve.
constantYValue
The Y-axis values are assumed constant until the next curve point and prior to the first curve point.
straightLineYValues
The Y-axis values are assumed to be a straight line between values. Also known as linear interpolation.
xUnit
The X-axis units of measure.
y1Unit
The Y1-axis units of measure.
y2Unit
The Y2-axis units of measure.
CurveData
Multi-purpose data points for defining a curve. The use of this generic class is discouraged if a more specific class can be used to specify the x and y axis values along with their specific data types.
xvalue
The data value of the X-axis variable, depending on the X-axis units.
y1value
The data value of the first Y-axis variable, depending on the Y-axis units.
y2value
The data value of the second Y-axis variable (if present), depending on the Y-axis units.
Equipment
The parts of a power system that are physical devices, electronic or mechanical.
aggregate
The single instance of equipment represents multiple pieces of equipment that have been modeled together as an aggregate. Examples would be power transformers or synchronous machines operating in parallel modeled as a single aggregate power transformer or aggregate synchronous machine. This is not to be used to indicate equipment that is part of a group of interdependent equipment produced by a network production program.
EquipmentContainer
A modeling construct to provide a root class for containing equipment.
GeographicalRegion
A geographical region of a power system network model.
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
energyIdentCodeEic
Entsoe
The attribute is used for an exchange of the EIC code (Energy identification Code). The length of the string is 16 characters as defined by the EIC code.
References:
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
shortName
Entsoe
The attribute is used for an exchange of a human readable short name with length of the string 12 characters maximum.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
RegularIntervalSchedule
The schedule has time points where the time between them is constant.
timeStep
The time between each pair of subsequent regular time points in sequence order.
Seconds
Time, in seconds.
CIMDatatype
value
Time, in seconds
unit
multiplier
endTime
The time for the last time point.
TimePoints
The regular interval time point data values that define this schedule.
No
IntervalSchedule
Regular interval schedule containing this time point.
Yes
RegularTimePoint
Time point for a schedule where the time between the consecutive points is constant.
Operation
sequenceNumber
The position of the regular time point in the sequence. Note that time points don't have to be sequential, i.e. time points may be omitted. The actual time for a RegularTimePoint is computed by multiplying the associated regular interval schedule's time step with the regular time point sequence number and adding the associated schedules start time.
value1
The first value at the time. The meaning of the value is defined by the derived type of the associated schedule.
value2
The second value at the time. The meaning of the value is defined by the derived type of the associated schedule.
ReportingGroup
A reporting group is used for various ad-hoc groupings used for reporting.
SubGeographicalRegion
A subset of a geographical region of a power system network model.
Substation
A collection of equipment for purposes other than generation or utilization, through which electric energy in bulk is passed for the purposes of switching or modifying its characteristics.
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
phases
Represents the normal network phasing condition.
If the attribute is missing three phases (ABC or ABCN) shall be assumed.
VoltageLevel
A collection of equipment at one common system voltage forming a switchgear. The equipment typically consist of breakers, busbars, instrumentation, control, regulation and protection devices as well as assemblies of all these.
highVoltageLimit
The bus bar's high voltage limit
lowVoltageLimit
The bus bar's low voltage limit
OperationalLimits
The OperationalLimits package models a specification of limits associated with equipment and other operational entities.
ActivePowerLimit
Limit on active power flow.
Operation
value
Value of active power limit.
ApparentPowerLimit
Apparent power limit.
Operation
value
The apparent power limit.
CurrentLimit
Operational limit on current.
value
Limit on current flow.
LimitTypeKind
The enumeration defines the kinds of the limit types.
Entsoe
patl
The Permanent Admissible Transmission Loading (PATL) is the loading in Amps, MVA or MW that can be accepted by a network branch for an unlimited duration without any risk for the material.
The duration attribute is not used and shall be excluded for the PATL limit type. Hence only one limit value exists for the PATL type.
patlt
Permanent Admissible Transmission Loading Threshold (PATLT) is a value in engineering units defined for PATL and calculated using percentage less than 100 of the PATL type intended to alert operators of an arising condition. The percentage should be given in the name of the OperationalLimitSet. The aceptableDuration is another way to express the severity of the limit.
tatl
Temporarily Admissible Transmission Loading (TATL) which is the loading in Amps, MVA or MW that can be accepted by a branch for a certain limited duration.
The TATL can be defined in different ways:
- as a fixed percentage of the PATL for a given time (for example, 115% of the PATL that can be accepted during 15 minutes),
- pairs of TATL type and Duration calculated for each line taking into account its particular configuration and conditions of functioning (for example, it can define a TATL acceptable during 20 minutes and another one acceptable during 10 minutes).
Such a definition of TATL can depend on the initial operating conditions of the network element (sag situation of a line).
The duration attribute can be used define several TATL limit types. Hence multiple TATL limit values may exist having different durations.
tc
Tripping Current (TC) is the ultimate intensity without any delay. It is defined as the threshold the line will trip without any possible remedial actions.
The tripping of the network element is ordered by protections against short circuits or by overload protections, but in any case, the activation delay of these protections is not compatible with the reaction delay of an operator (less than one minute).
The duration is always zero and the duration attribute may be left out. Hence only one limit value exists for the TC type.
tct
Tripping Current Threshold (TCT) is a value in engineering units defined for TC and calculated using percentage less than 100 of the TC type intended to alert operators of an arising condition. The percentage should be given in the name of the OperationalLimitSet. The aceptableDuration is another way to express the severity of the limit.
highVoltage
Referring to the rating of the equipments, a voltage too high can lead to accelerated ageing or the destruction of the equipment.
This limit type may or may not have duration.
lowVoltage
A too low voltage can disturb the normal operation of some protections and transformer equipped with on-load tap changers, electronic power devices or can affect the behaviour of the auxiliaries of generation units.
This limit type may or may not have duration.
OperationalLimit
A value associated with a specific kind of limit.
The sub class value attribute shall be positive.
The sub class value attribute is inversely proportional to OperationalLimitType.acceptableDuration (acceptableDuration for short). A pair of value_x and acceptableDuration_x are related to each other as follows:
if value_1 > value_2 > value_3 >... then
acceptableDuration_1 < acceptableDuration_2 < acceptableDuration_3 < ...
A value_x with direction="high" shall be greater than a value_y with direction="low".
OperationalLimitDirectionKind
The direction attribute describes the side of a limit that is a violation.
high
High means that a monitored value above the limit value is a violation. If applied to a terminal flow, the positive direction is into the terminal.
low
Low means a monitored value below the limit is a violation. If applied to a terminal flow, the positive direction is into the terminal.
absoluteValue
An absoluteValue limit means that a monitored absolute value above the limit value is a violation.
OperationalLimitSet
A set of limits associated with equipment. Sets of limits might apply to a specific temperature, or season for example. A set of limits may contain different severities of limit levels that would apply to the same equipment. The set may contain limits of different types such as apparent power and current limits or high and low voltage limits that are logically applied together as a set.
OperationalLimitType
The operational meaning of a category of limits.
acceptableDuration
The nominal acceptable duration of the limit. Limits are commonly expressed in terms of the a time limit for which the limit is normally acceptable. The actual acceptable duration of a specific limit may depend on other local factors such as temperature or wind speed.
limitType
Entsoe
Types of limits defined in the ENTSO-E Operational Handbook Policy 3.
direction
The direction of the limit.
VoltageLimit
Operational limit applied to voltage.
value
Limit on voltage. High or low limit nature of the limit depends upon the properties of the operational limit type.
Wires
An extension to the Core and Topology package that models information on the electrical characteristics of Transmission and Distribution networks. This package is used by network applications such as State Estimation, Load Flow and Optimal Power Flow.
ACLineSegment
A wire or combination of wires, with consistent electrical characteristics, building a single electrical system, used to carry alternating current between points in the power system.
For symmetrical, transposed 3ph lines, it is sufficient to use attributes of the line segment, which describe impedances and admittances for the entire length of the segment. Additionally impedances can be computed by using length and associated per length impedances.
The BaseVoltage at the two ends of ACLineSegments in a Line shall have the same BaseVoltage.nominalVoltage. However, boundary lines may have slightly different BaseVoltage.nominalVoltages and variation is allowed. Larger voltage difference in general requires use of an equivalent branch.
Susceptance
Imaginary part of admittance.
CIMDatatype
value
unit
multiplier
bch
Positive sequence shunt (charging) susceptance, uniformly distributed, of the entire line section. This value represents the full charging over the full length of the line.
Conductance
Factor by which voltage must be multiplied to give corresponding power lost from a circuit. Real part of admittance.
CIMDatatype
value
unit
multiplier
gch
Positive sequence shunt (charging) conductance, uniformly distributed, of the entire line section.
r
Positive sequence series resistance of the entire line section.
Temperature
Value of temperature in degrees Celsius.
CIMDatatype
multiplier
unit
value
x
Positive sequence series reactance of the entire line section.
AsynchronousMachine
A rotating machine whose shaft rotates asynchronously with the electrical field. Also known as an induction machine with no external connection to the rotor windings, e.g squirrel-cage induction machine.
nominalFrequency
Nameplate data indicates if the machine is 50 or 60 Hz.
Frequency
Cycles per second.
CIMDatatype
value
unit
multiplier
nominalSpeed
Nameplate data. Depends on the slip and number of pole pairs.
RotationSpeed
Number of revolutions per second.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
Breaker
A mechanical switching device capable of making, carrying, and breaking currents under normal circuit conditions and also making, carrying for a specified time, and breaking currents under specified abnormal circuit conditions e.g. those of short circuit.
BusbarSection
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation.
Voltage measurements are typically obtained from VoltageTransformers that are connected to busbar sections. A bus bar section may have many physical terminals but for analysis is modelled with exactly one logical terminal.
Conductor
Combination of conducting material with consistent electrical characteristics, building a single electrical system, used to carry current between points in the power system.
length
Segment length for calculating line section capabilities
Connector
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation and are modelled with a single logical terminal.
Disconnector
A manually operated or motor operated mechanical switching device used for changing the connections in a circuit, or for isolating a circuit or equipment from a source of power. It is required to open or close circuits when negligible current is broken or made.
EnergyConsumer
Generic user of energy - a point of consumption on the power system model.
pfixed
Operation
Active power of the load that is a fixed quantity. Load sign convention is used, i.e. positive sign means flow out from a node.
pfixedPct
Operation
Fixed active power as per cent of load group fixed active power. Load sign convention is used, i.e. positive sign means flow out from a node.
qfixed
Operation
Reactive power of the load that is a fixed quantity. Load sign convention is used, i.e. positive sign means flow out from a node.
ReactivePower
Product of RMS value of the voltage and the RMS value of the quadrature component of the current.
CIMDatatype
value
unit
multiplier
qfixedPct
Operation
Fixed reactive power as per cent of load group fixed reactive power. Load sign convention is used, i.e. positive sign means flow out from a node.
ExternalNetworkInjection
This class represents external network and it is used for IEC 60909 calculations.
governorSCD
Power Frequency Bias. This is the change in power injection divided by the change in frequency and negated. A positive value of the power frequency bias provides additional power injection upon a drop in frequency.
ActivePowerPerFrequency
Active power variation with frequency.
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
maxP
Maximum active power of the injection.
maxQ
Not for short circuit modelling; It is used for modelling of infeed for load flow exchange. If maxQ and minQ are not used ReactiveCapabilityCurve can be used
minP
Minimum active power of the injection.
minQ
Not for short circuit modelling; It is used for modelling of infeed for load flow exchange. If maxQ and minQ are not used ReactiveCapabilityCurve can be used
PU
Per Unit - a positive or negative value referred to a defined base. Values typically range from -10 to +10.
CIMDatatype
value
unit
multiplier
Ground
A point where the system is grounded used for connecting conducting equipment to ground. The power system model can have any number of grounds.
ShortCircuit
Operation
GroundDisconnector
A manually operated or motor operated mechanical switching device used for isolating a circuit or equipment from ground.
ShortCircuit
Operation
Junction
A point where one or more conducting equipments are connected with zero resistance.
Line
Contains equipment beyond a substation belonging to a power transmission line.
LinearShuntCompensator
A linear shunt compensator has banks or sections with equal admittance values.
bPerSection
Positive sequence shunt (charging) susceptance per section
gPerSection
Positive sequence shunt (charging) conductance per section
LoadBreakSwitch
A mechanical switching device capable of making, carrying, and breaking currents under normal operating conditions.
NonlinearShuntCompensator
A non linear shunt compensator has bank or section admittance values that differs.
NonlinearShuntCompensatorPoint
A non linear shunt compensator bank or section admittance value.
b
Positive sequence shunt (charging) susceptance per section
g
Positive sequence shunt (charging) conductance per section
sectionNumber
The number of the section.
PetersenCoilModeKind
The mode of operation for a Petersen coil.
fixed
Fixed position.
manual
Manual positioning.
automaticPositioning
Automatic positioning.
PhaseTapChanger
A transformer phase shifting tap model that controls the phase angle difference across the power transformer and potentially the active power flow through the power transformer. This phase tap model may also impact the voltage magnitude.
PhaseTapChangerAsymmetrical
Describes the tap model for an asymmetrical phase shifting transformer in which the difference voltage vector adds to the primary side voltage. The angle between the primary side voltage and the difference voltage is named the winding connection angle. The phase shift depends on both the difference voltage magnitude and the winding connection angle.
windingConnectionAngle
The phase angle between the in-phase winding and the out-of -phase winding used for creating phase shift. The out-of-phase winding produces what is known as the difference voltage. Setting this angle to 90 degrees is not the same as a symmemtrical transformer.
PhaseTapChangerLinear
Describes a tap changer with a linear relation between the tap step and the phase angle difference across the transformer. This is a mathematical model that is an approximation of a real phase tap changer.
The phase angle is computed as stepPhaseShitfIncrement times the tap position.
The secondary side voltage magnitude is the same as at the primary side.
stepPhaseShiftIncrement
Phase shift per step position. A positive value indicates a positive phase shift from the winding where the tap is located to the other winding (for a two-winding transformer).
The actual phase shift increment might be more accurately computed from the symmetrical or asymmetrical models or a tap step table lookup if those are available.
xMax
The reactance depend on the tap position according to a "u" shaped curve. The maximum reactance (xMax) appear at the low and high tap positions.
xMin
The reactance depend on the tap position according to a "u" shaped curve. The minimum reactance (xMin) appear at the mid tap position.
PhaseTapChangerNonLinear
The non-linear phase tap changer describes the non-linear behavior of a phase tap changer. This is a base class for the symmetrical and asymmetrical phase tap changer models. The details of these models can be found in the IEC 61970-301 document.
voltageStepIncrement
The voltage step increment on the out of phase winding specified in percent of nominal voltage of the transformer end.
xMax
The reactance depend on the tap position according to a "u" shaped curve. The maximum reactance (xMax) appear at the low and high tap positions.
xMin
The reactance depend on the tap position according to a "u" shaped curve. The minimum reactance (xMin) appear at the mid tap position.
PhaseTapChangerSymmetrical
Describes a symmetrical phase shifting transformer tap model in which the secondary side voltage magnitude is the same as at the primary side. The difference voltage magnitude is the base in an equal-sided triangle where the sides corresponds to the primary and secondary voltages. The phase angle difference corresponds to the top angle and can be expressed as twice the arctangent of half the total difference voltage.
PhaseTapChangerTable
Describes a tabular curve for how the phase angle difference and impedance varies with the tap step.
PhaseTapChangerTablePoint
Describes each tap step in the phase tap changer tabular curve.
angle
The angle difference in degrees.
PhaseTapChangerTabular
PowerTransformer
An electrical device consisting of two or more coupled windings, with or without a magnetic core, for introducing mutual coupling between electric circuits. Transformers can be used to control voltage and phase shift (active power flow).
A power transformer may be composed of separate transformer tanks that need not be identical.
A power transformer can be modeled with or without tanks and is intended for use in both balanced and unbalanced representations. A power transformer typically has two terminals, but may have one (grounding), three or more terminals.
The inherited association ConductingEquipment.BaseVoltage should not be used. The association from TransformerEnd to BaseVoltage should be used instead.
PowerTransformerEnd
A PowerTransformerEnd is associated with each Terminal of a PowerTransformer.
The impedance values r, r0, x, and x0 of a PowerTransformerEnd represents a star equivalent as follows
1) for a two Terminal PowerTransformer the high voltage PowerTransformerEnd has non zero values on r, r0, x, and x0 while the low voltage PowerTransformerEnd has zero values for r, r0, x, and x0.
2) for a three Terminal PowerTransformer the three PowerTransformerEnds represents a star equivalent with each leg in the star represented by r, r0, x, and x0 values.
3) for a PowerTransformer with more than three Terminals the PowerTransformerEnd impedance values cannot be used. Instead use the TransformerMeshImpedance or split the transformer into multiple PowerTransformers.
b
Magnetizing branch susceptance (B mag). The value can be positive or negative.
connectionKind
Kind of connection.
WindingConnection
Winding connection type.
D
Delta
Y
Wye
Z
ZigZag
Yn
Wye, with neutral brought out for grounding.
Zn
ZigZag, with neutral brought out for grounding.
A
Autotransformer common winding
I
Independent winding, for single-phase connections
ratedS
Normal apparent power rating.
The attribute shall be a positive value. For a two-winding transformer the values for the high and low voltage sides shall be identical.
g
Magnetizing branch conductance.
ratedU
Rated voltage: phase-phase for three-phase windings, and either phase-phase or phase-neutral for single-phase windings.
A high voltage side, as given by TransformerEnd.endNumber, shall have a ratedU that is greater or equal than ratedU for the lower voltage sides.
r
Resistance (star-model) of the transformer end.
The attribute shall be equal or greater than zero for non-equivalent transformers.
x
Positive sequence series reactance (star-model) of the transformer end.
ProtectedSwitch
A ProtectedSwitch is a switching device that can be operated by ProtectionEquipment.
RatioTapChanger
A tap changer that changes the voltage ratio impacting the voltage magnitude but not the phase angle across the transformer.
tculControlMode
Specifies the regulation control mode (voltage or reactive) of the RatioTapChanger.
TransformerControlMode
Control modes for a transformer.
volt
Voltage control
reactive
Reactive power flow control
stepVoltageIncrement
Tap step increment, in per cent of nominal voltage, per step position.
RatioTapChangerTable
Describes a curve for how the voltage magnitude and impedance varies with the tap step.
RatioTapChangerTablePoint
Describes each tap step in the ratio tap changer tabular curve.
ReactiveCapabilityCurve
Reactive power rating envelope versus the synchronous machine's active power, in both the generating and motoring modes. For each active power value there is a corresponding high and low reactive power limit value. Typically there will be a separate curve for each coolant condition, such as hydrogen pressure. The Y1 axis values represent reactive minimum and the Y2 axis values represent reactive maximum.
RegulatingCondEq
A type of conducting equipment that can regulate a quantity (i.e. voltage or flow) at a specific point in the network.
RegulatingControl
Specifies a set of equipment that works together to control a power system quantity such as voltage or flow.
Remote bus voltage control is possible by specifying the controlled terminal located at some place remote from the controlling equipment.
In case multiple equipment, possibly of different types, control same terminal there must be only one RegulatingControl at that terminal. The most specific subtype of RegulatingControl shall be used in case such equipment participate in the control, e.g. TapChangerControl for tap changers.
For flow control load sign convention is used, i.e. positive sign means flow out from a TopologicalNode (bus) into the conducting equipment.
mode
The regulating control mode presently available. This specification allows for determining the kind of regulation without need for obtaining the units from a schedule.
RegulatingControlModeKind
The kind of regulation model. For example regulating voltage, reactive power, active power, etc.
voltage
Voltage is specified.
activePower
Active power is specified.
reactivePower
Reactive power is specified.
currentFlow
Current flow is specified.
admittance
Admittance is specified.
timeScheduled
Control switches on/off by time of day. The times may change on the weekend, or in different seasons.
temperature
Control switches on/off based on the local temperature (i.e., a thermostat).
powerFactor
Power factor is specified.
RegulatingControl
Regulating controls that have this Schedule.
Yes
RegulationSchedule
Schedule for this Regulating regulating control.
No
RegulationSchedule
A pre-established pattern over time for a controlled variable, e.g., busbar voltage.
Operation
RotatingMachine
A rotating machine which may be used as a generator or motor.
ratedPowerFactor
Power factor (nameplate data). It is primarily used for short circuit data exchange according to IEC 60909.
ratedS
Nameplate apparent power rating for the unit.
The attribute shall have a positive value.
ratedU
Rated voltage (nameplate data, Ur in IEC 60909-0). It is primarily used for short circuit data exchange according to IEC 60909.
SeriesCompensator
A Series Compensator is a series capacitor or reactor or an AC transmission line without charging susceptance. It is a two terminal device.
r
Positive sequence resistance.
x
Positive sequence reactance.
varistorPresent
Describe if a metal oxide varistor (mov) for over voltage protection is configured at the series compensator.
varistorRatedCurrent
The maximum current the varistor is designed to handle at specified duration.
varistorVoltageThreshold
The dc voltage at which the varistor start conducting.
ShortCircuitRotorKind
Type of rotor, used by short circuit applications.
salientPole1
Salient pole 1 in the IEC 60909
salientPole2
Salient pole 2 in IEC 60909
turboSeries1
Turbo Series 1 in the IEC 60909
turboSeries2
Turbo series 2 in IEC 60909
ShuntCompensator
A shunt capacitor or reactor or switchable bank of shunt capacitors or reactors. A section of a shunt compensator is an individual capacitor or reactor. A negative value for reactivePerSection indicates that the compensator is a reactor. ShuntCompensator is a single terminal device. Ground is implied.
aVRDelay
Time delay required for the device to be connected or disconnected by automatic voltage regulation (AVR).
grounded
Used for Yn and Zn connections. True if the neutral is solidly grounded.
maximumSections
The maximum number of sections that may be switched in.
nomU
The voltage at which the nominal reactive power may be calculated. This should normally be within 10% of the voltage at which the capacitor is connected to the network.
normalSections
The normal number of sections switched in.
switchOnCount
The switch on count since the capacitor count was last reset or initialized.
switchOnDate
The date and time when the capacitor bank was last switched on.
voltageSensitivity
Voltage sensitivity required for the device to regulate the bus voltage, in voltage/reactive power.
VoltagePerReactivePower
Voltage variation with reactive power.
CIMDatatype
value
unit
denominatorMultiplier
multiplier
denominatorUnit
StaticVarCompensator
A facility for providing variable and controllable shunt reactive power. The SVC typically consists of a stepdown transformer, filter, thyristor-controlled reactor, and thyristor-switched capacitor arms.
The SVC may operate in fixed MVar output mode or in voltage control mode. When in voltage control mode, the output of the SVC will be proportional to the deviation of voltage at the controlled bus from the voltage setpoint. The SVC characteristic slope defines the proportion. If the voltage at the controlled bus is equal to the voltage setpoint, the SVC MVar output is zero.
capacitiveRating
Maximum available capacitive reactance.
inductiveRating
Maximum available inductive reactance.
slope
The characteristics slope of an SVC defines how the reactive power output changes in proportion to the difference between the regulated bus voltage and the voltage setpoint.
sVCControlMode
SVC control mode.
SVCControlMode
Static VAr Compensator control mode.
reactivePower
voltage
voltageSetPoint
The reactive power output of the SVC is proportional to the difference between the voltage at the regulated bus and the voltage setpoint. When the regulated bus voltage is equal to the voltage setpoint, the reactive power output is zero.
Switch
A generic device designed to close, or open, or both, one or more electric circuits. All switches are two terminal devices including grounding switches.
normalOpen
The attribute is used in cases when no Measurement for the status value is present. If the Switch has a status measurement the Discrete.normalValue is expected to match with the Switch.normalOpen.
ratedCurrent
The maximum continuous current carrying capacity in amps governed by the device material and construction.
retained
Branch is retained in a bus branch model. The flow through retained switches will normally be calculated in power flow.
Switch
A Switch can be associated with SwitchSchedules.
Yes
SwitchSchedules
A SwitchSchedule is associated with a Switch.
No
SwitchSchedule
A schedule of switch positions. If RegularTimePoint.value1 is 0, the switch is open. If 1, the switch is closed.
Operation
SynchronousMachine
An electromechanical device that operates with shaft rotating synchronously with the network. It is a single machine operating either as a generator or synchronous condenser or pump.
maxQ
Maximum reactive power limit. This is the maximum (nameplate) limit for the unit.
minQ
Minimum reactive power limit for the unit.
qPercent
Percent of the coordinated reactive control that comes from this machine.
type
Modes that this synchronous machine can operate in.
SynchronousMachineKind
Synchronous machine type.
generator
condenser
generatorOrCondenser
motor
generatorOrMotor
motorOrCondenser
generatorOrCondenserOrMotor
TapChanger
Mechanism for changing transformer winding tap positions.
highStep
Highest possible tap step position, advance from neutral.
The attribute shall be greater than lowStep.
lowStep
Lowest possible tap step position, retard from neutral
ltcFlag
Specifies whether or not a TapChanger has load tap changing capabilities.
neutralStep
The neutral tap step position for this winding.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
neutralU
Voltage at which the winding operates at the neutral tap setting.
normalStep
The tap step position used in "normal" network operation for this winding. For a "Fixed" tap changer indicates the current physical tap setting.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
TapSchedules
A TapSchedule is associated with a TapChanger.
No
TapChanger
A TapChanger can have TapSchedules.
Yes
TapChangerControl
Describes behavior specific to tap changers, e.g. how the voltage at the end of a line varies with the load level and compensation of the voltage drop by tap adjustment.
TapChangerTablePoint
b
The magnetizing branch susceptance deviation in percent of nominal value. The actual susceptance is calculated as follows:
calculated magnetizing susceptance = b(nominal) * (1 + b(from this class)/100). The b(nominal) is defined as the static magnetizing susceptance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
g
The magnetizing branch conductance deviation in percent of nominal value. The actual conductance is calculated as follows:
calculated magnetizing conductance = g(nominal) * (1 + g(from this class)/100). The g(nominal) is defined as the static magnetizing conductance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
r
The resistance deviation in percent of nominal value. The actual reactance is calculated as follows:
calculated resistance = r(nominal) * (1 + r(from this class)/100). The r(nominal) is defined as the static resistance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
ratio
The voltage ratio in per unit. Hence this is a value close to one.
step
The tap step.
x
The series reactance deviation in percent of nominal value. The actual reactance is calculated as follows:
calculated reactance = x(nominal) * (1 + x(from this class)/100). The x(nominal) is defined as the static series reactance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
TapSchedule
A pre-established pattern over time for a tap step.
Operation
TransformerEnd
A conducting connection point of a power transformer. It corresponds to a physical transformer winding terminal. In earlier CIM versions, the TransformerWinding class served a similar purpose, but this class is more flexible because it associates to terminal but is not a specialization of ConductingEquipment.
endNumber
Number for this transformer end, corresponding to the end's order in the power transformer vector group or phase angle clock number. Highest voltage winding should be 1. Each end within a power transformer should have a unique subsequent end number. Note the transformer end number need not match the terminal sequence number.
LoadModel
This package is responsible for modeling the energy consumers and the system load as curves and associated curve data. Special circumstances that may affect the load, such as seasons and daytypes, are also included here.
This information is used by Load Forecasting and Load Management.
ConformLoad
ConformLoad represent loads that follow a daily load change pattern where the pattern can be used to scale the load with a system load.
ConformLoadGroup
A group of loads conforming to an allocation pattern.
ConformLoadSchedule
A curve of load versus time (X-axis) showing the active power values (Y1-axis) and reactive power (Y2-axis) for each unit of the period covered. This curve represents a typical pattern of load over the time period for a given day type and season.
DayType
Group of similar days. For example it could be used to represent weekdays, weekend, or holidays.
Operation
DayType
Schedules that use this DayType.
Yes
SeasonDayTypeSchedules
DayType for the Schedule.
No
EnergyArea
Describes an area having energy production or consumption. Specializations are intended to support the load allocation function as typically required in energy management systems or planning studies to allocate hypothesized load levels to individual load points for power flow analysis. Often the energy area can be linked to both measured and forecast load levels.
Operation
EnergyArea
The energy area that is forecast from this control area specification.
Yes
Operation
ControlArea
The control area specification that is used for the load forecast.
No
Operation
LoadArea
The class is the root or first level in a hierarchical structure for grouping of loads for the purpose of load flow load scaling.
Operation
SubLoadAreas
The SubLoadAreas in the LoadArea.
No
LoadArea
The LoadArea where the SubLoadArea belongs.
Yes
LoadGroup
The class is the third level in a hierarchical structure for grouping of loads for the purpose of load flow load scaling.
LoadGroups
The Loadgroups in the SubLoadArea.
No
SubLoadArea
The SubLoadArea where the Loadgroup belongs.
Yes
LoadResponseCharacteristic
Models the characteristic response of the load demand due to changes in system conditions such as voltage and frequency. This is not related to demand response.
If LoadResponseCharacteristic.exponentModel is True, the voltage exponents are specified and used as to calculate:
Active power component = Pnominal * (Voltage/cim:BaseVoltage.nominalVoltage) ** cim:LoadResponseCharacteristic.pVoltageExponent
Reactive power component = Qnominal * (Voltage/cim:BaseVoltage.nominalVoltage)** cim:LoadResponseCharacteristic.qVoltageExponent
Where * means "multiply" and ** is "raised to power of".
exponentModel
Indicates the exponential voltage dependency model is to be used. If false, the coefficient model is to be used.
The exponential voltage dependency model consist of the attributes
- pVoltageExponent
- qVoltageExponent.
The coefficient model consist of the attributes
- pConstantImpedance
- pConstantCurrent
- pConstantPower
- qConstantImpedance
- qConstantCurrent
- qConstantPower.
The sum of pConstantImpedance, pConstantCurrent and pConstantPower shall equal 1.
The sum of qConstantImpedance, qConstantCurrent and qConstantPower shall equal 1.
pConstantCurrent
Portion of active power load modeled as constant current.
pConstantImpedance
Portion of active power load modeled as constant impedance.
pConstantPower
Portion of active power load modeled as constant power.
pFrequencyExponent
Exponent of per unit frequency effecting active power.
pVoltageExponent
Exponent of per unit voltage effecting real power.
qConstantCurrent
Portion of reactive power load modeled as constant current.
qConstantImpedance
Portion of reactive power load modeled as constant impedance.
qConstantPower
Portion of reactive power load modeled as constant power.
qFrequencyExponent
Exponent of per unit frequency effecting reactive power.
qVoltageExponent
Exponent of per unit voltage effecting reactive power.
NonConformLoad
NonConformLoad represent loads that do not follow a daily load change pattern and changes are not correlated with the daily load change pattern.
NonConformLoadGroup
Loads that do not follow a daily and seasonal load variation pattern.
NonConformLoadSchedule
An active power (Y1-axis) and reactive power (Y2-axis) schedule (curves) versus time (X-axis) for non-conforming loads, e.g., large industrial load or power station service (where modeled).
Season
A specified time period of the year.
Operation
endDate
Date season ends.
MonthDay
MonthDay format as "--mm-dd", which conforms with XSD data type gMonthDay.
Primitive
startDate
Date season starts.
Season
Schedules that use this Season.
Yes
SeasonDayTypeSchedules
Season for the Schedule.
No
SeasonDayTypeSchedule
A time schedule covering a 24 hour period, with curve data for a specific type of season and day.
Operation
StationSupply
Station supply with load derived from the station output.
Operation
SubLoadArea
The class is the second level in a hierarchical structure for grouping of loads for the purpose of load flow load scaling.
Operation
Equivalents
The equivalents package models equivalent networks.
EquivalentBranch
The class represents equivalent branches.
r
Positive sequence series resistance of the reduced branch.
r21
Resistance from terminal sequence 2 to terminal sequence 1 .Used for steady state power flow. This attribute is optional and represent unbalanced network such as off-nominal phase shifter. If only EquivalentBranch.r is given, then EquivalentBranch.r21 is assumed equal to EquivalentBranch.r.
Usage rule : EquivalentBranch is a result of network reduction prior to the data exchange.
x
Positive sequence series reactance of the reduced branch.
x21
Reactance from terminal sequence 2 to terminal sequence 1 .Used for steady state power flow. This attribute is optional and represent unbalanced network such as off-nominal phase shifter. If only EquivalentBranch.x is given, then EquivalentBranch.x21 is assumed equal to EquivalentBranch.x.
Usage rule : EquivalentBranch is a result of network reduction prior to the data exchange.
EquivalentEquipment
The class represents equivalent objects that are the result of a network reduction. The class is the base for equivalent objects of different types.
EquivalentInjection
This class represents equivalent injections (generation or load). Voltage regulation is allowed only at the point of connection.
maxP
Maximum active power of the injection.
maxQ
Used for modeling of infeed for load flow exchange. Not used for short circuit modeling. If maxQ and minQ are not used ReactiveCapabilityCurve can be used.
minP
Minimum active power of the injection.
minQ
Used for modeling of infeed for load flow exchange. Not used for short circuit modeling. If maxQ and minQ are not used ReactiveCapabilityCurve can be used.
regulationCapability
Specifies whether or not the EquivalentInjection has the capability to regulate the local voltage.
EquivalentNetwork
A class that represents an external meshed network that has been reduced to an electrically equivalent model. The ConnectivityNodes contained in the equivalent are intended to reflect internal nodes of the equivalent. The boundary Connectivity nodes where the equivalent connects outside itself are NOT contained by the equivalent.
EquivalentShunt
The class represents equivalent shunts.
b
Positive sequence shunt susceptance.
g
Positive sequence shunt conductance.
ControlArea
The ControlArea package models area specifications which can be used for a variety of purposes. The package as a whole models potentially overlapping control area specifications for the purpose of actual generation control, load forecast area load capture, or powerflow based analysis.
ControlArea
A control area is a grouping of generating units and/or loads and a cutset of tie lines (as terminals) which may be used for a variety of purposes including automatic generation control, powerflow solution area interchange control specification, and input to load forecasting. Note that any number of overlapping control area specifications can be superimposed on the physical model.
type
The primary type of control area definition used to determine if this is used for automatic generation control, for planning interchange control, or other purposes. A control area specified with primary type of automatic generation control could still be forecast and used as an interchange area in power flow analysis.
ControlAreaTypeKind
The type of control area.
AGC
Used for automatic generation control.
Forecast
Used for load forecast.
Interchange
Used for interchange specification or control.
ControlAreaGeneratingUnit
A control area generating unit. This class is needed so that alternate control area definitions may include the same generating unit. Note only one instance within a control area should reference a specific generating unit.
TieFlow
A flow specification in terms of location and direction for a control area.
positiveFlowIn
True if the flow into the terminal (load convention) is also flow into the control area. For example, this attribute should be true if using the tie line terminal further away from the control area. For example to represent a tie to a shunt component (like a load or generator) in another area, this is the near end of a branch and this attribute would be specified as false.
PK ! Yɇ R cimpyorm/res/schemata/CIM16/EquipmentProfileCoreRDFSAugmented-v2_4_15-4Jul2016.rdf
EquipmentProfile
This profile has been built on the basis of the IEC 61970-452 document and adjusted to fit the purpose of the ENTSO-E CGMES.
EquipmentVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURIcore
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
baseURIoperation
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
baseURIshortCircuit
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURIcore
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentCore/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIoperation
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentOperation/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIshortCircuit
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentShortCircuit/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
DC
ACDCConverter
A unit with valves for three phases, together with unit control equipment, essential protective and switching devices, DC storage capacitors, phase reactors and auxiliaries, if any, used for conversion.
baseS
Base apparent power of the converter pole.
ApparentPower
Product of the RMS value of the voltage and the RMS value of the current.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
idleLoss
Active power loss in pole at no power transfer. Converter configuration data used in power flow.
ActivePower
Product of RMS value of the voltage and the RMS value of the in-phase component of the current.
CIMDatatype
value
unit
multiplier
maxUdc
The maximum voltage on the DC side at which the converter should operate. Converter configuration data used in power flow.
Voltage
Electrical voltage, can be both AC and DC.
CIMDatatype
value
unit
multiplier
minUdc
Min allowed converter DC voltage. Converter configuration data used in power flow.
numberOfValves
Number of valves in the converter. Used in loss calculations.
Integer
An integer number. The range is unspecified and not limited.
Primitive
ratedUdc
Rated converter DC voltage, also called UdN. Converter configuration data used in power flow.
resistiveLoss
Converter configuration data used in power flow. Refer to poleLossP.
Resistance
Resistance (real part of impedance).
CIMDatatype
value
unit
multiplier
switchingLoss
Switching losses, relative to the base apparent power 'baseS'.
Refer to poleLossP.
ActivePowerPerCurrentFlow
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
valveU0
Valve threshold voltage. Forward voltage drop when the valve is conducting. Used in loss calculations, i.e. the switchLoss depend on numberOfValves * valveU0.
DCConductingEquipment
Yes
DCTerminals
No
ConverterDCSides
Point of common coupling terminal for this converter DC side. It is typically the terminal on the power transformer (or switch) closest to the AC network. The power flow measurement must be the sum of all flows into the transformer.
No
PccTerminal
All converters' DC sides linked to this point of common coupling terminal.
Yes
ACDCConverterDCTerminal
A DC electrical connection point at the AC/DC converter. The AC/DC converter is electrically connected also to the AC side. The AC connection is inherited from the AC conducting equipment in the same way as any other AC equipment. The AC/DC converter DC terminal is separate from generic DC terminal to restrict the connection with the AC side to AC/DC converter and so that no other DC conducting equipment can be connected to the AC side.
polarity
Represents the normal network polarity condition.
DCPolarityKind
Polarity for DC circuits.
positive
Positive pole.
middle
Middle pole, potentially grounded.
negative
Negative pole.
CsConverter
DC side of the current source converter (CSC).
maxAlpha
Maximum firing angle. CSC configuration data used in power flow.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
multiplier
maxGamma
Maximum extinction angle. CSC configuration data used in power flow.
maxIdc
The maximum direct current (Id) on the DC side at which the converter should operate. Converter configuration data use in power flow.
CurrentFlow
Electrical current with sign convention: positive flow is out of the conducting equipment into the connectivity node. Can be both AC and DC.
CIMDatatype
value
unit
multiplier
minAlpha
Minimum firing angle. CSC configuration data used in power flow.
minGamma
Minimum extinction angle. CSC configuration data used in power flow.
minIdc
The minimum direct current (Id) on the DC side at which the converter should operate. CSC configuration data used in power flow.
ratedIdc
Rated converter DC current, also called IdN. Converter configuration data used in power flow.
DCBaseTerminal
An electrical connection point at a piece of DC conducting equipment. DC terminals are connected at one physical DC node that may have multiple DC terminals connected. A DC node is similar to an AC connectivity node. The model enforces that DC connections are distinct from AC connections.
DCTerminals
No
DCNode
Yes
DCBreaker
A breaker within a DC system.
DCBusbar
A busbar within a DC system.
DCChopper
Low resistance equipment used in the internal DC circuit to balance voltages. It has typically positive and negative pole terminals and a ground.
DCConductingEquipment
The parts of the DC power system that are designed to carry current or that are conductively connected through DC terminals.
DCTerminals
No
DCConductingEquipment
Yes
DCConverterOperatingModeKind
The operating mode of an HVDC bipole.
bipolar
Bipolar operation.
monopolarMetallicReturn
Monopolar operation with metallic return
monopolarGroundReturn
Monopolar operation with ground return
DCConverterUnit
Indivisible operative unit comprising all equipment between the point of common coupling on the AC side and the point of common coupling – DC side, essentially one or more converters, together with one or more converter transformers, converter control equipment, essential protective and switching devices and auxiliaries, if any, used for conversion.
operationMode
Substation
Yes
DCConverterUnit
No
DCDisconnector
A disconnector within a DC system.
DCEquipmentContainer
A modeling construct to provide a root class for containment of DC as well as AC equipment. The class differ from the EquipmentContaner for AC in that it may also contain DCNodes. Hence it can contain both AC and DC equipment.
DCEquipmentContainer
Yes
DCNodes
No
DCGround
A ground within a DC system.
inductance
Inductance to ground.
Inductance
Inductive part of reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
r
Resistance to ground.
DCLine
Overhead lines and/or cables connecting two or more HVDC substations.
Region
Yes
DCLines
No
DCLineSegment
A wire or combination of wires not insulated from one another, with consistent electrical characteristics, used to carry direct current between points in the DC region of the power system.
capacitance
Capacitance of the DC line segment. Significant for cables only.
Capacitance
Capacitive part of reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
inductance
Inductance of the DC line segment. Neglectable compared with DCSeriesDevice used for smoothing.
resistance
Resistance of the DC line segment.
length
Segment length for calculating line section capabilities.
Length
Unit of length. Never negative.
CIMDatatype
value
unit
multiplier
DCLineSegments
All line segments described by this set of per-length parameters.
No
PerLengthParameter
Set of per-length parameters for this line segment.
Yes
DCNode
DC nodes are points where terminals of DC conducting equipment are connected together with zero impedance.
DCSeriesDevice
A series device within the DC system, typically a reactor used for filtering or smoothing. Needed for transient and short circuit studies.
inductance
Inductance of the device.
resistance
Resistance of the DC device.
ratedUdc
Rated DC device voltage. Converter configuration data used in power flow.
DCShunt
A shunt device within the DC system, typically used for filtering. Needed for transient and short circuit studies.
capacitance
Capacitance of the DC shunt.
resistance
Resistance of the DC device.
ratedUdc
Rated DC device voltage. Converter configuration data used in power flow.
DCSwitch
A switch within the DC system.
DCTerminal
An electrical connection point to generic DC conducting equipment.
PerLengthDCLineParameter
capacitance
Capacitance per unit of length of the DC line segment; significant for cables only.
CapacitancePerLength
Capacitance per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
inductance
Inductance per unit of length of the DC line segment.
InductancePerLength
Inductance per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
resistance
Resistance per length of the DC line segment.
ResistancePerLength
Resistance (real part of impedance) per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
VsCapabilityCurve
The P-Q capability curve for a voltage source converter, with P on x-axis and Qmin and Qmax on y1-axis and y2-axis.
VsConverterDCSides
Capability curve of this converter.
No
CapabilityCurve
All converters with this capability curve.
Yes
VsConverter
DC side of the voltage source converter (VSC).
maxModulationIndex
The max quotient between the AC converter voltage (Uc) and DC voltage (Ud). A factor typically less than 1. VSC configuration data used in power flow.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
maxValveCurrent
The maximum current through a valve. This current limit is the basis for calculating the capability diagram. VSC configuration data.
Topology
BusNameMarker
Used to apply user standard names to topology buses. Typically used for "bus/branch" case generation. Associated with one or more terminals that are normally connected with the bus name. The associated terminals are normally connected by non-retained switches. For a ring bus station configuration, all busbar terminals in the ring are typically associated. For a breaker and a half scheme, both busbars would normally be associated. For a ring bus, all busbars would normally be associated. For a "straight" busbar configuration, normally only the main terminal at the busbar would be associated.
priority
Priority of bus name marker for use as topology bus name. Use 0 for don t care. Use 1 for highest priority. Use 2 as priority is less than 1 and so on.
BusNameMarker
The reporting group to which this bus name marker belongs.
No
ReportingGroup
The bus name markers that belong to this reporting group.
Yes
Terminal
The terminals associated with this bus name marker.
No
BusNameMarker
The bus name marker used to name the bus (topological node).
Yes
Meas
Boolean
A type with the value space "true" and "false".
Primitive
DateTime
Date and time as "yyyy-mm-ddThh:mm:ss.sss", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddThh:mm:ss.sssZ". A local timezone relative UTC is specified as "yyyy-mm-ddThh:mm:ss.sss-hh:mm". The second component (shown here as "ss.sss") could have any number of digits in its fractional part to allow any kind of precision beyond seconds.
Primitive
PhaseCode
Enumeration of phase identifiers. Allows designation of phases for both transmission and distribution equipment, circuits and loads.
Residential and small commercial loads are often served from single-phase, or split-phase, secondary circuits. For example of s12N, phases 1 and 2 refer to hot wires that are 180 degrees out of phase, while N refers to the neutral wire. Through single-phase transformer connections, these secondary circuits may be served from one or two of the primary phases A, B, and C. For three-phase loads, use the A, B, C phase codes instead of s12N.
ABCN
Phases A, B, C, and N.
ABC
Phases A, B, and C.
ABN
Phases A, B, and neutral.
ACN
Phases A, C and neutral.
BCN
Phases B, C, and neutral.
AB
Phases A and B.
AC
Phases A and C.
BC
Phases B and C.
AN
Phases A and neutral.
BN
Phases B and neutral.
CN
Phases C and neutral.
A
Phase A.
B
Phase B.
C
Phase C.
N
Neutral phase.
s1N
Secondary phase 1 and neutral.
s2N
Secondary phase 2 and neutral.
s12N
Secondary phases 1, 2, and neutral.
s1
Secondary phase 1.
s2
Secondary phase 2.
s12
Secondary phase 1 and 2.
PerCent
Percentage on a defined base. For example, specify as 100 to indicate at the defined base.
CIMDatatype
value
Normally 0 - 100 on a defined base
unit
multiplier
Source
Source gives information related to the origin of a value.
PROCESS
The value is provided by input from the process I/O or being calculated from some function.
DEFAULTED
The value contains a default value.
SUBSTITUTED
The value is provided by input of an operator or by an automatic source.
Validity
Validity for MeasurementValue.
GOOD
The value is marked good if no abnormal condition of the acquisition function or the information source is detected.
QUESTIONABLE
The value is marked questionable if a supervision function detects an abnormal behaviour, however the value could still be valid. The client is responsible for determining whether or not values marked "questionable" should be used.
INVALID
The value is marked invalid when a supervision function recognises abnormal conditions of the acquisition function or the information source (missing or non-operating updating devices). The value is not defined under this condition. The mark invalid is used to indicate to the client that the value may be incorrect and shall not be used.
Production
The production package is responsible for classes which describe various kinds of generators. These classes also provide production costing information which is used to economically allocate demand among committed units and calculate reserve quantities.
EnergySchedulingType
Used to define the type of generation for scheduling purposes.
Entsoe
EnergySource
Energy Scheduling Type of an Energy Source
No
EnergySchedulingType
Energy Source of a particular Energy Scheduling Type
Yes
EnergySource
A generic equivalent for an energy supplier on a transmission or distribution voltage level.
nominalVoltage
Phase-to-phase nominal voltage.
r
Positive sequence Thevenin resistance.
r0
Zero sequence Thevenin resistance.
rn
Negative sequence Thevenin resistance.
voltageAngle
Phase angle of a-phase open circuit.
AngleRadians
Phase angle in radians.
CIMDatatype
value
unit
multiplier
voltageMagnitude
Phase-to-phase open circuit voltage magnitude.
x
Positive sequence Thevenin reactance.
Reactance
Reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
x0
Zero sequence Thevenin reactance.
xn
Negative sequence Thevenin reactance.
FossilFuel
The fossil fuel consumed by the non-nuclear thermal generating unit. For example, coal, oil, gas, etc. This a the specific fuels that the generating unit can consume.
fossilFuelType
The type of fossil fuel, such as coal, oil, or gas.
FuelType
Type of fuel.
coal
Generic coal, not including lignite type.
oil
Oil.
gas
Natural gas.
lignite
The fuel is lignite coal. Note that this is a special type of coal, so the other enum of coal is reserved for hard coal types or if the exact type of coal is not known.
hardCoal
Hard coal
oilShale
Oil Shale
FossilFuels
A thermal generating unit may have one or more fossil fuels.
No
ThermalGeneratingUnit
A thermal generating unit may have one or more fossil fuels.
Yes
GeneratingUnit
A single or set of synchronous machines for converting mechanical power into alternating-current power. For example, individual machines within a set may be defined for scheduling purposes while a single control signal is derived for the set. In this case there would be a GeneratingUnit for each member of the set and an additional GeneratingUnit corresponding to the set.
genControlSource
The source of controls for a generating unit.
GeneratorControlSource
The source of controls for a generating unit.
unavailable
Not available.
offAGC
Off of automatic generation control (AGC).
onAGC
On automatic generation control (AGC).
plantControl
Plant is controlling.
governorSCD
Governor Speed Changer Droop. This is the change in generator power output divided by the change in frequency normalized by the nominal power of the generator and the nominal frequency and expressed in percent and negated. A positive value of speed change droop provides additional generator output upon a drop in frequency.
initialP
Default initial active power which is used to store a powerflow result for the initial active power for this unit in this network configuration.
longPF
Generating unit long term economic participation factor.
maximumAllowableSpinningReserve
Maximum allowable spinning reserve. Spinning reserve will never be considered greater than this value regardless of the current operating point.
maxOperatingP
This is the maximum operating active power limit the dispatcher can enter for this unit.
minOperatingP
This is the minimum operating active power limit the dispatcher can enter for this unit.
nominalP
The nominal power of the generating unit. Used to give precise meaning to percentage based attributes such as the governor speed change droop (governorSCD attribute).
The attribute shall be a positive value equal or less than RotatingMachine.ratedS.
ratedGrossMaxP
The unit's gross rated maximum capacity (book value).
ratedGrossMinP
The gross rated minimum generation level which the unit can safely operate at while delivering power to the transmission grid.
ratedNetMaxP
The net rated maximum capacity determined by subtracting the auxiliary power used to operate the internal plant machinery from the rated gross maximum capacity.
shortPF
Generating unit short term economic participation factor.
startupCost
The initial startup cost incurred for each start of the GeneratingUnit.
Money
Amount of money.
CIMDatatype
unit
Currency
Monetary currencies. Apologies for this list not being exhaustive.
USD
US dollar
EUR
European euro
AUD
Australian dollar
CAD
Canadian dollar
CHF
Swiss francs
CNY
Chinese yuan renminbi
DKK
Danish crown
GBP
British pound
JPY
Japanese yen
NOK
Norwegian crown
RUR
Russian ruble
SEK
Swedish crown
INR
India rupees
other
Another type of currency.
multiplier
value
Decimal
Decimal is the base-10 notational system for representing real numbers.
Primitive
variableCost
The variable cost component of production per unit of ActivePower.
totalEfficiency
The efficiency of the unit in converting the fuel into electrical energy.
GeneratingUnit
The generating unit specified for this control area. Note that a control area should include a GeneratingUnit only once.
Yes
ControlAreaGeneratingUnit
ControlArea specifications for this generating unit.
No
GeneratingUnit
A synchronous machine may operate as a generator and as such becomes a member of a generating unit.
Yes
RotatingMachine
A synchronous machine may operate as a generator and as such becomes a member of a generating unit.
No
HydroEnergyConversionKind
Specifies the capability of the hydro generating unit to convert energy as a generator or pump.
generator
Able to generate power, but not able to pump water for energy storage.
pumpAndGenerator
Able to both generate power and pump water for energy storage.
HydroGeneratingUnit
A generating unit whose prime mover is a hydraulic turbine (e.g., Francis, Pelton, Kaplan).
energyConversionCapability
Energy conversion capability for generating.
HydroGeneratingUnits
The hydro generating unit belongs to a hydro power plant.
No
HydroPowerPlant
The hydro generating unit belongs to a hydro power plant.
Yes
HydroPlantStorageKind
The type of hydro power plant.
runOfRiver
Run of river.
pumpedStorage
Pumped storage.
storage
Storage.
HydroPowerPlant
A hydro power station which can generate or pump. When generating, the generator turbines receive water from an upper reservoir. When pumping, the pumps receive their water from a lower reservoir.
hydroPlantStorageType
The type of hydro power plant water storage.
HydroPumps
The hydro pump may be a member of a pumped storage plant or a pump for distributing water.
No
HydroPowerPlant
The hydro pump may be a member of a pumped storage plant or a pump for distributing water.
Yes
HydroPump
A synchronous motor-driven pump, typically associated with a pumped storage plant.
RotatingMachine
The synchronous machine drives the turbine which moves the water from a low elevation to a higher elevation. The direction of machine rotation for pumping may or may not be the same as for generating.
Yes
HydroPump
The synchronous machine drives the turbine which moves the water from a low elevation to a higher elevation. The direction of machine rotation for pumping may or may not be the same as for generating.
No
NuclearGeneratingUnit
A nuclear generating unit.
SolarGeneratingUnit
A solar thermal generating unit.
ThermalGeneratingUnit
A generating unit whose prime mover could be a steam turbine, combustion turbine, or diesel engine.
WindGeneratingUnit
A wind driven generating unit. May be used to represent a single turbine or an aggregation.
windGenUnitType
The kind of wind generating unit
WindGenUnitKind
Kind of wind generating unit.
offshore
The wind generating unit is located offshore.
onshore
The wind generating unit is located onshore.
Core
Contains the core PowerSystemResource and ConductingEquipment entities shared by all applications plus common collections of those entities. Not all applications require all the Core entities. This package does not depend on any other package except the Domain package, but most of the other packages have associations and generalizations that depend on it.
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
sequenceNumber
The orientation of the terminal connections for a multiple terminal conducting equipment. The sequence numbering starts with 1 and additional terminals should follow in increasing order. The first terminal is the "starting point" for a two terminal branch.
Terminal
Yes
OperationalLimitSet
No
BaseVoltage
Defines a system base voltage which is referenced.
nominalVoltage
The power system resource's base voltage.
BaseVoltage
All conducting equipment with this base voltage. Use only when there is no voltage level container used and only one base voltage applies. For example, not used for transformers.
Yes
ConductingEquipment
Base voltage of this conducting equipment. Use only when there is no voltage level container used and only one base voltage applies. For example, not used for transformers.
No
BaseVoltage
The base voltage used for all equipment within the voltage level.
Yes
VoltageLevel
The voltage levels having this base voltage.
No
BaseVoltage
Base voltage of the transformer end. This is essential for PU calculation.
Yes
TransformerEnds
Transformer ends at the base voltage. This is essential for PU calculation.
No
BasicIntervalSchedule
Schedule of values at points in time.
startTime
The time for the first time point.
value1Unit
Value1 units of measure.
value2Unit
Value2 units of measure.
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
ConductingEquipment
The conducting equipment of the terminal. Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
Yes
Terminals
Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
No
ConnectivityNodeContainer
A base class for all objects that may contain connectivity nodes or topological nodes.
Curve
A multi-purpose curve or functional relationship between an independent variable (X-axis) and dependent (Y-axis) variables.
curveStyle
The style or shape of the curve.
CurveStyle
Style or shape of curve.
constantYValue
The Y-axis values are assumed constant until the next curve point and prior to the first curve point.
straightLineYValues
The Y-axis values are assumed to be a straight line between values. Also known as linear interpolation.
xUnit
The X-axis units of measure.
y1Unit
The Y1-axis units of measure.
y2Unit
The Y2-axis units of measure.
CurveDatas
The curve of this curve data point.
No
Curve
The point data values that define this curve.
Yes
CurveData
Multi-purpose data points for defining a curve. The use of this generic class is discouraged if a more specific class can be used to specify the x and y axis values along with their specific data types.
xvalue
The data value of the X-axis variable, depending on the X-axis units.
y1value
The data value of the first Y-axis variable, depending on the Y-axis units.
y2value
The data value of the second Y-axis variable (if present), depending on the Y-axis units.
Equipment
The parts of a power system that are physical devices, electronic or mechanical.
aggregate
The single instance of equipment represents multiple pieces of equipment that have been modeled together as an aggregate. Examples would be power transformers or synchronous machines operating in parallel modeled as a single aggregate power transformer or aggregate synchronous machine. This is not to be used to indicate equipment that is part of a group of interdependent equipment produced by a network production program.
Equipments
Contained equipment.
No
EquipmentContainer
Container of this equipment.
Yes
Equipment
The equipment to which the limit set applies.
Yes
OperationalLimitSet
The operational limit sets associated with this equipment.
No
EquipmentContainer
A modeling construct to provide a root class for containing equipment.
GeographicalRegion
A geographical region of a power system network model.
Regions
All sub-geograhpical regions within this geographical region.
No
Region
The geographical region to which this sub-geographical region is within.
Yes
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
energyIdentCodeEic
Entsoe
The attribute is used for an exchange of the EIC code (Energy identification Code). The length of the string is 16 characters as defined by the EIC code.
References:
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
shortName
Entsoe
The attribute is used for an exchange of a human readable short name with length of the string 12 characters maximum.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
RegularIntervalSchedule
The schedule has time points where the time between them is constant.
timeStep
The time between each pair of subsequent regular time points in sequence order.
Seconds
Time, in seconds.
CIMDatatype
value
Time, in seconds
unit
multiplier
endTime
The time for the last time point.
ReportingGroup
A reporting group is used for various ad-hoc groupings used for reporting.
SubGeographicalRegion
A subset of a geographical region of a power system network model.
Lines
The lines within the sub-geographical region.
No
Region
The sub-geographical region of the line.
Yes
Substations
The substations in this sub-geographical region.
No
Region
The SubGeographicalRegion containing the substation.
Yes
Substation
A collection of equipment for purposes other than generation or utilization, through which electric energy in bulk is passed for the purposes of switching or modifying its characteristics.
VoltageLevels
The voltage levels within this substation.
No
Substation
The substation of the voltage level.
Yes
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
phases
Represents the normal network phasing condition.
If the attribute is missing three phases (ABC or ABCN) shall be assumed.
Terminal
The controls regulating this terminal.
Yes
RegulatingControl
The terminal associated with this regulating control. The terminal is associated instead of a node, since the terminal could connect into either a topological node (bus in bus-branch model) or a connectivity node (detailed switch model). Sometimes it is useful to model regulation at a terminal of a bus bar object since the bus bar can be present in both a bus-branch model or a model with switch detail.
No
Terminal
The terminal to which this tie flow belongs.
Yes
TieFlow
The control area tie flows to which this terminal associates.
No
Terminal
Terminal of the power transformer to which this transformer end belongs.
Yes
TransformerEnd
All transformer ends connected at this terminal.
No
VoltageLevel
A collection of equipment at one common system voltage forming a switchgear. The equipment typically consist of breakers, busbars, instrumentation, control, regulation and protection devices as well as assemblies of all these.
highVoltageLimit
The bus bar's high voltage limit
lowVoltageLimit
The bus bar's low voltage limit
OperationalLimits
The OperationalLimits package models a specification of limits associated with equipment and other operational entities.
CurrentLimit
Operational limit on current.
value
Limit on current flow.
LimitTypeKind
The enumeration defines the kinds of the limit types.
Entsoe
patl
The Permanent Admissible Transmission Loading (PATL) is the loading in Amps, MVA or MW that can be accepted by a network branch for an unlimited duration without any risk for the material.
The duration attribute is not used and shall be excluded for the PATL limit type. Hence only one limit value exists for the PATL type.
patlt
Permanent Admissible Transmission Loading Threshold (PATLT) is a value in engineering units defined for PATL and calculated using percentage less than 100 of the PATL type intended to alert operators of an arising condition. The percentage should be given in the name of the OperationalLimitSet. The aceptableDuration is another way to express the severity of the limit.
tatl
Temporarily Admissible Transmission Loading (TATL) which is the loading in Amps, MVA or MW that can be accepted by a branch for a certain limited duration.
The TATL can be defined in different ways:
- as a fixed percentage of the PATL for a given time (for example, 115% of the PATL that can be accepted during 15 minutes),
- pairs of TATL type and Duration calculated for each line taking into account its particular configuration and conditions of functioning (for example, it can define a TATL acceptable during 20 minutes and another one acceptable during 10 minutes).
Such a definition of TATL can depend on the initial operating conditions of the network element (sag situation of a line).
The duration attribute can be used define several TATL limit types. Hence multiple TATL limit values may exist having different durations.
tc
Tripping Current (TC) is the ultimate intensity without any delay. It is defined as the threshold the line will trip without any possible remedial actions.
The tripping of the network element is ordered by protections against short circuits or by overload protections, but in any case, the activation delay of these protections is not compatible with the reaction delay of an operator (less than one minute).
The duration is always zero and the duration attribute may be left out. Hence only one limit value exists for the TC type.
tct
Tripping Current Threshold (TCT) is a value in engineering units defined for TC and calculated using percentage less than 100 of the TC type intended to alert operators of an arising condition. The percentage should be given in the name of the OperationalLimitSet. The aceptableDuration is another way to express the severity of the limit.
highVoltage
Referring to the rating of the equipments, a voltage too high can lead to accelerated ageing or the destruction of the equipment.
This limit type may or may not have duration.
lowVoltage
A too low voltage can disturb the normal operation of some protections and transformer equipped with on-load tap changers, electronic power devices or can affect the behaviour of the auxiliaries of generation units.
This limit type may or may not have duration.
OperationalLimit
A value associated with a specific kind of limit.
The sub class value attribute shall be positive.
The sub class value attribute is inversely proportional to OperationalLimitType.acceptableDuration (acceptableDuration for short). A pair of value_x and acceptableDuration_x are related to each other as follows:
if value_1 > value_2 > value_3 >... then
acceptableDuration_1 < acceptableDuration_2 < acceptableDuration_3 < ...
A value_x with direction="high" shall be greater than a value_y with direction="low".
OperationalLimitValue
The limit set to which the limit values belong.
No
OperationalLimitSet
Values of equipment limits.
Yes
OperationalLimitType
The limit type associated with this limit.
Yes
OperationalLimit
The operational limits associated with this type of limit.
No
OperationalLimitDirectionKind
The direction attribute describes the side of a limit that is a violation.
high
High means that a monitored value above the limit value is a violation. If applied to a terminal flow, the positive direction is into the terminal.
low
Low means a monitored value below the limit is a violation. If applied to a terminal flow, the positive direction is into the terminal.
absoluteValue
An absoluteValue limit means that a monitored absolute value above the limit value is a violation.
OperationalLimitSet
A set of limits associated with equipment. Sets of limits might apply to a specific temperature, or season for example. A set of limits may contain different severities of limit levels that would apply to the same equipment. The set may contain limits of different types such as apparent power and current limits or high and low voltage limits that are logically applied together as a set.
OperationalLimitType
The operational meaning of a category of limits.
acceptableDuration
The nominal acceptable duration of the limit. Limits are commonly expressed in terms of the a time limit for which the limit is normally acceptable. The actual acceptable duration of a specific limit may depend on other local factors such as temperature or wind speed.
limitType
Entsoe
Types of limits defined in the ENTSO-E Operational Handbook Policy 3.
direction
The direction of the limit.
VoltageLimit
Operational limit applied to voltage.
value
Limit on voltage. High or low limit nature of the limit depends upon the properties of the operational limit type.
Wires
An extension to the Core and Topology package that models information on the electrical characteristics of Transmission and Distribution networks. This package is used by network applications such as State Estimation, Load Flow and Optimal Power Flow.
ACLineSegment
A wire or combination of wires, with consistent electrical characteristics, building a single electrical system, used to carry alternating current between points in the power system.
For symmetrical, transposed 3ph lines, it is sufficient to use attributes of the line segment, which describe impedances and admittances for the entire length of the segment. Additionally impedances can be computed by using length and associated per length impedances.
The BaseVoltage at the two ends of ACLineSegments in a Line shall have the same BaseVoltage.nominalVoltage. However, boundary lines may have slightly different BaseVoltage.nominalVoltages and variation is allowed. Larger voltage difference in general requires use of an equivalent branch.
Susceptance
Imaginary part of admittance.
CIMDatatype
value
unit
multiplier
bch
Positive sequence shunt (charging) susceptance, uniformly distributed, of the entire line section. This value represents the full charging over the full length of the line.
Conductance
Factor by which voltage must be multiplied to give corresponding power lost from a circuit. Real part of admittance.
CIMDatatype
value
unit
multiplier
gch
Positive sequence shunt (charging) conductance, uniformly distributed, of the entire line section.
r
Positive sequence series resistance of the entire line section.
Temperature
Value of temperature in degrees Celsius.
CIMDatatype
multiplier
unit
value
x
Positive sequence series reactance of the entire line section.
AsynchronousMachine
A rotating machine whose shaft rotates asynchronously with the electrical field. Also known as an induction machine with no external connection to the rotor windings, e.g squirrel-cage induction machine.
nominalFrequency
Nameplate data indicates if the machine is 50 or 60 Hz.
Frequency
Cycles per second.
CIMDatatype
value
unit
multiplier
nominalSpeed
Nameplate data. Depends on the slip and number of pole pairs.
RotationSpeed
Number of revolutions per second.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
Breaker
A mechanical switching device capable of making, carrying, and breaking currents under normal circuit conditions and also making, carrying for a specified time, and breaking currents under specified abnormal circuit conditions e.g. those of short circuit.
BusbarSection
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation.
Voltage measurements are typically obtained from VoltageTransformers that are connected to busbar sections. A bus bar section may have many physical terminals but for analysis is modelled with exactly one logical terminal.
Conductor
Combination of conducting material with consistent electrical characteristics, building a single electrical system, used to carry current between points in the power system.
length
Segment length for calculating line section capabilities
Connector
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation and are modelled with a single logical terminal.
Disconnector
A manually operated or motor operated mechanical switching device used for changing the connections in a circuit, or for isolating a circuit or equipment from a source of power. It is required to open or close circuits when negligible current is broken or made.
EnergyConsumer
Generic user of energy - a point of consumption on the power system model.
ReactivePower
Product of RMS value of the voltage and the RMS value of the quadrature component of the current.
CIMDatatype
value
unit
multiplier
LoadResponse
The load response characteristic of this load. If missing, this load is assumed to be constant power.
Yes
EnergyConsumer
The set of loads that have the response characteristics.
No
ExternalNetworkInjection
This class represents external network and it is used for IEC 60909 calculations.
governorSCD
Power Frequency Bias. This is the change in power injection divided by the change in frequency and negated. A positive value of the power frequency bias provides additional power injection upon a drop in frequency.
ActivePowerPerFrequency
Active power variation with frequency.
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
maxP
Maximum active power of the injection.
maxQ
Not for short circuit modelling; It is used for modelling of infeed for load flow exchange. If maxQ and minQ are not used ReactiveCapabilityCurve can be used
minP
Minimum active power of the injection.
minQ
Not for short circuit modelling; It is used for modelling of infeed for load flow exchange. If maxQ and minQ are not used ReactiveCapabilityCurve can be used
PU
Per Unit - a positive or negative value referred to a defined base. Values typically range from -10 to +10.
CIMDatatype
value
unit
multiplier
Junction
A point where one or more conducting equipments are connected with zero resistance.
Line
Contains equipment beyond a substation belonging to a power transmission line.
LinearShuntCompensator
A linear shunt compensator has banks or sections with equal admittance values.
bPerSection
Positive sequence shunt (charging) susceptance per section
gPerSection
Positive sequence shunt (charging) conductance per section
LoadBreakSwitch
A mechanical switching device capable of making, carrying, and breaking currents under normal operating conditions.
NonlinearShuntCompensator
A non linear shunt compensator has bank or section admittance values that differs.
NonlinearShuntCompensator
Non-linear shunt compensator owning this point.
Yes
NonlinearShuntCompensatorPoints
All points of the non-linear shunt compensator.
No
NonlinearShuntCompensatorPoint
A non linear shunt compensator bank or section admittance value.
b
Positive sequence shunt (charging) susceptance per section
g
Positive sequence shunt (charging) conductance per section
sectionNumber
The number of the section.
PetersenCoilModeKind
The mode of operation for a Petersen coil.
fixed
Fixed position.
manual
Manual positioning.
automaticPositioning
Automatic positioning.
PhaseTapChanger
A transformer phase shifting tap model that controls the phase angle difference across the power transformer and potentially the active power flow through the power transformer. This phase tap model may also impact the voltage magnitude.
TransformerEnd
Phase tap changer associated with this transformer end.
Yes
PhaseTapChanger
Transformer end to which this phase tap changer belongs.
No
PhaseTapChangerAsymmetrical
Describes the tap model for an asymmetrical phase shifting transformer in which the difference voltage vector adds to the primary side voltage. The angle between the primary side voltage and the difference voltage is named the winding connection angle. The phase shift depends on both the difference voltage magnitude and the winding connection angle.
windingConnectionAngle
The phase angle between the in-phase winding and the out-of -phase winding used for creating phase shift. The out-of-phase winding produces what is known as the difference voltage. Setting this angle to 90 degrees is not the same as a symmemtrical transformer.
PhaseTapChangerLinear
Describes a tap changer with a linear relation between the tap step and the phase angle difference across the transformer. This is a mathematical model that is an approximation of a real phase tap changer.
The phase angle is computed as stepPhaseShitfIncrement times the tap position.
The secondary side voltage magnitude is the same as at the primary side.
stepPhaseShiftIncrement
Phase shift per step position. A positive value indicates a positive phase shift from the winding where the tap is located to the other winding (for a two-winding transformer).
The actual phase shift increment might be more accurately computed from the symmetrical or asymmetrical models or a tap step table lookup if those are available.
xMax
The reactance depend on the tap position according to a "u" shaped curve. The maximum reactance (xMax) appear at the low and high tap positions.
xMin
The reactance depend on the tap position according to a "u" shaped curve. The minimum reactance (xMin) appear at the mid tap position.
PhaseTapChangerNonLinear
The non-linear phase tap changer describes the non-linear behavior of a phase tap changer. This is a base class for the symmetrical and asymmetrical phase tap changer models. The details of these models can be found in the IEC 61970-301 document.
voltageStepIncrement
The voltage step increment on the out of phase winding specified in percent of nominal voltage of the transformer end.
xMax
The reactance depend on the tap position according to a "u" shaped curve. The maximum reactance (xMax) appear at the low and high tap positions.
xMin
The reactance depend on the tap position according to a "u" shaped curve. The minimum reactance (xMin) appear at the mid tap position.
PhaseTapChangerSymmetrical
Describes a symmetrical phase shifting transformer tap model in which the secondary side voltage magnitude is the same as at the primary side. The difference voltage magnitude is the base in an equal-sided triangle where the sides corresponds to the primary and secondary voltages. The phase angle difference corresponds to the top angle and can be expressed as twice the arctangent of half the total difference voltage.
PhaseTapChangerTable
Describes a tabular curve for how the phase angle difference and impedance varies with the tap step.
PhaseTapChangerTable
The table of this point.
Yes
PhaseTapChangerTablePoint
The points of this table.
No
PhaseTapChangerTabular
The phase tap changers to which this phase tap table applies.
No
PhaseTapChangerTable
The phase tap changer table for this phase tap changer.
Yes
PhaseTapChangerTablePoint
Describes each tap step in the phase tap changer tabular curve.
angle
The angle difference in degrees.
PhaseTapChangerTabular
PowerTransformer
An electrical device consisting of two or more coupled windings, with or without a magnetic core, for introducing mutual coupling between electric circuits. Transformers can be used to control voltage and phase shift (active power flow).
A power transformer may be composed of separate transformer tanks that need not be identical.
A power transformer can be modeled with or without tanks and is intended for use in both balanced and unbalanced representations. A power transformer typically has two terminals, but may have one (grounding), three or more terminals.
The inherited association ConductingEquipment.BaseVoltage should not be used. The association from TransformerEnd to BaseVoltage should be used instead.
PowerTransformer
The ends of this power transformer.
Yes
PowerTransformerEnd
The power transformer of this power transformer end.
No
PowerTransformerEnd
A PowerTransformerEnd is associated with each Terminal of a PowerTransformer.
The impedance values r, r0, x, and x0 of a PowerTransformerEnd represents a star equivalent as follows
1) for a two Terminal PowerTransformer the high voltage PowerTransformerEnd has non zero values on r, r0, x, and x0 while the low voltage PowerTransformerEnd has zero values for r, r0, x, and x0.
2) for a three Terminal PowerTransformer the three PowerTransformerEnds represents a star equivalent with each leg in the star represented by r, r0, x, and x0 values.
3) for a PowerTransformer with more than three Terminals the PowerTransformerEnd impedance values cannot be used. Instead use the TransformerMeshImpedance or split the transformer into multiple PowerTransformers.
b
Magnetizing branch susceptance (B mag). The value can be positive or negative.
connectionKind
Kind of connection.
WindingConnection
Winding connection type.
D
Delta
Y
Wye
Z
ZigZag
Yn
Wye, with neutral brought out for grounding.
Zn
ZigZag, with neutral brought out for grounding.
A
Autotransformer common winding
I
Independent winding, for single-phase connections
ratedS
Normal apparent power rating.
The attribute shall be a positive value. For a two-winding transformer the values for the high and low voltage sides shall be identical.
g
Magnetizing branch conductance.
ratedU
Rated voltage: phase-phase for three-phase windings, and either phase-phase or phase-neutral for single-phase windings.
A high voltage side, as given by TransformerEnd.endNumber, shall have a ratedU that is greater or equal than ratedU for the lower voltage sides.
r
Resistance (star-model) of the transformer end.
The attribute shall be equal or greater than zero for non-equivalent transformers.
x
Positive sequence series reactance (star-model) of the transformer end.
ProtectedSwitch
A ProtectedSwitch is a switching device that can be operated by ProtectionEquipment.
RatioTapChanger
A tap changer that changes the voltage ratio impacting the voltage magnitude but not the phase angle across the transformer.
tculControlMode
Specifies the regulation control mode (voltage or reactive) of the RatioTapChanger.
TransformerControlMode
Control modes for a transformer.
volt
Voltage control
reactive
Reactive power flow control
stepVoltageIncrement
Tap step increment, in per cent of nominal voltage, per step position.
RatioTapChanger
The tap ratio table for this ratio tap changer.
No
RatioTapChangerTable
The ratio tap changer of this tap ratio table.
Yes
TransformerEnd
Ratio tap changer associated with this transformer end.
Yes
RatioTapChanger
Transformer end to which this ratio tap changer belongs.
No
RatioTapChangerTable
Describes a curve for how the voltage magnitude and impedance varies with the tap step.
RatioTapChangerTablePoint
Table of this point.
No
RatioTapChangerTable
Points of this table.
Yes
RatioTapChangerTablePoint
Describes each tap step in the ratio tap changer tabular curve.
ReactiveCapabilityCurve
Reactive power rating envelope versus the synchronous machine's active power, in both the generating and motoring modes. For each active power value there is a corresponding high and low reactive power limit value. Typically there will be a separate curve for each coolant condition, such as hydrogen pressure. The Y1 axis values represent reactive minimum and the Y2 axis values represent reactive maximum.
ReactiveCapabilityCurve
The equivalent injection using this reactive capability curve.
Yes
EquivalentInjection
The reactive capability curve used by this equivalent injection.
No
InitialReactiveCapabilityCurve
Synchronous machines using this curve as default.
Yes
InitiallyUsedBySynchronousMachines
The default reactive capability curve for use by a synchronous machine.
No
RegulatingCondEq
A type of conducting equipment that can regulate a quantity (i.e. voltage or flow) at a specific point in the network.
RegulatingControl
The regulating control scheme in which this equipment participates.
Yes
RegulatingCondEq
The equipment that participates in this regulating control scheme.
No
RegulatingControl
Specifies a set of equipment that works together to control a power system quantity such as voltage or flow.
Remote bus voltage control is possible by specifying the controlled terminal located at some place remote from the controlling equipment.
In case multiple equipment, possibly of different types, control same terminal there must be only one RegulatingControl at that terminal. The most specific subtype of RegulatingControl shall be used in case such equipment participate in the control, e.g. TapChangerControl for tap changers.
For flow control load sign convention is used, i.e. positive sign means flow out from a TopologicalNode (bus) into the conducting equipment.
mode
The regulating control mode presently available. This specification allows for determining the kind of regulation without need for obtaining the units from a schedule.
RegulatingControlModeKind
The kind of regulation model. For example regulating voltage, reactive power, active power, etc.
voltage
Voltage is specified.
activePower
Active power is specified.
reactivePower
Reactive power is specified.
currentFlow
Current flow is specified.
admittance
Admittance is specified.
timeScheduled
Control switches on/off by time of day. The times may change on the weekend, or in different seasons.
temperature
Control switches on/off based on the local temperature (i.e., a thermostat).
powerFactor
Power factor is specified.
RotatingMachine
A rotating machine which may be used as a generator or motor.
ratedPowerFactor
Power factor (nameplate data). It is primarily used for short circuit data exchange according to IEC 60909.
ratedS
Nameplate apparent power rating for the unit.
The attribute shall have a positive value.
ratedU
Rated voltage (nameplate data, Ur in IEC 60909-0). It is primarily used for short circuit data exchange according to IEC 60909.
SeriesCompensator
A Series Compensator is a series capacitor or reactor or an AC transmission line without charging susceptance. It is a two terminal device.
r
Positive sequence resistance.
x
Positive sequence reactance.
varistorPresent
Describe if a metal oxide varistor (mov) for over voltage protection is configured at the series compensator.
varistorRatedCurrent
The maximum current the varistor is designed to handle at specified duration.
varistorVoltageThreshold
The dc voltage at which the varistor start conducting.
ShortCircuitRotorKind
Type of rotor, used by short circuit applications.
salientPole1
Salient pole 1 in the IEC 60909
salientPole2
Salient pole 2 in IEC 60909
turboSeries1
Turbo Series 1 in the IEC 60909
turboSeries2
Turbo series 2 in IEC 60909
ShuntCompensator
A shunt capacitor or reactor or switchable bank of shunt capacitors or reactors. A section of a shunt compensator is an individual capacitor or reactor. A negative value for reactivePerSection indicates that the compensator is a reactor. ShuntCompensator is a single terminal device. Ground is implied.
aVRDelay
Time delay required for the device to be connected or disconnected by automatic voltage regulation (AVR).
grounded
Used for Yn and Zn connections. True if the neutral is solidly grounded.
maximumSections
The maximum number of sections that may be switched in.
nomU
The voltage at which the nominal reactive power may be calculated. This should normally be within 10% of the voltage at which the capacitor is connected to the network.
normalSections
The normal number of sections switched in.
switchOnCount
The switch on count since the capacitor count was last reset or initialized.
switchOnDate
The date and time when the capacitor bank was last switched on.
voltageSensitivity
Voltage sensitivity required for the device to regulate the bus voltage, in voltage/reactive power.
VoltagePerReactivePower
Voltage variation with reactive power.
CIMDatatype
value
unit
denominatorMultiplier
multiplier
denominatorUnit
StaticVarCompensator
A facility for providing variable and controllable shunt reactive power. The SVC typically consists of a stepdown transformer, filter, thyristor-controlled reactor, and thyristor-switched capacitor arms.
The SVC may operate in fixed MVar output mode or in voltage control mode. When in voltage control mode, the output of the SVC will be proportional to the deviation of voltage at the controlled bus from the voltage setpoint. The SVC characteristic slope defines the proportion. If the voltage at the controlled bus is equal to the voltage setpoint, the SVC MVar output is zero.
capacitiveRating
Maximum available capacitive reactance.
inductiveRating
Maximum available inductive reactance.
slope
The characteristics slope of an SVC defines how the reactive power output changes in proportion to the difference between the regulated bus voltage and the voltage setpoint.
sVCControlMode
SVC control mode.
SVCControlMode
Static VAr Compensator control mode.
reactivePower
voltage
voltageSetPoint
The reactive power output of the SVC is proportional to the difference between the voltage at the regulated bus and the voltage setpoint. When the regulated bus voltage is equal to the voltage setpoint, the reactive power output is zero.
Switch
A generic device designed to close, or open, or both, one or more electric circuits. All switches are two terminal devices including grounding switches.
normalOpen
The attribute is used in cases when no Measurement for the status value is present. If the Switch has a status measurement the Discrete.normalValue is expected to match with the Switch.normalOpen.
ratedCurrent
The maximum continuous current carrying capacity in amps governed by the device material and construction.
retained
Branch is retained in a bus branch model. The flow through retained switches will normally be calculated in power flow.
SynchronousMachine
An electromechanical device that operates with shaft rotating synchronously with the network. It is a single machine operating either as a generator or synchronous condenser or pump.
maxQ
Maximum reactive power limit. This is the maximum (nameplate) limit for the unit.
minQ
Minimum reactive power limit for the unit.
qPercent
Percent of the coordinated reactive control that comes from this machine.
type
Modes that this synchronous machine can operate in.
SynchronousMachineKind
Synchronous machine type.
generator
condenser
generatorOrCondenser
motor
generatorOrMotor
motorOrCondenser
generatorOrCondenserOrMotor
TapChanger
Mechanism for changing transformer winding tap positions.
highStep
Highest possible tap step position, advance from neutral.
The attribute shall be greater than lowStep.
lowStep
Lowest possible tap step position, retard from neutral
ltcFlag
Specifies whether or not a TapChanger has load tap changing capabilities.
neutralStep
The neutral tap step position for this winding.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
neutralU
Voltage at which the winding operates at the neutral tap setting.
normalStep
The tap step position used in "normal" network operation for this winding. For a "Fixed" tap changer indicates the current physical tap setting.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
TapChanger
The regulating control scheme in which this tap changer participates.
No
TapChangerControl
The tap changers that participates in this regulating tap control scheme.
Yes
TapChangerControl
Describes behavior specific to tap changers, e.g. how the voltage at the end of a line varies with the load level and compensation of the voltage drop by tap adjustment.
TapChangerTablePoint
b
The magnetizing branch susceptance deviation in percent of nominal value. The actual susceptance is calculated as follows:
calculated magnetizing susceptance = b(nominal) * (1 + b(from this class)/100). The b(nominal) is defined as the static magnetizing susceptance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
g
The magnetizing branch conductance deviation in percent of nominal value. The actual conductance is calculated as follows:
calculated magnetizing conductance = g(nominal) * (1 + g(from this class)/100). The g(nominal) is defined as the static magnetizing conductance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
r
The resistance deviation in percent of nominal value. The actual reactance is calculated as follows:
calculated resistance = r(nominal) * (1 + r(from this class)/100). The r(nominal) is defined as the static resistance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
ratio
The voltage ratio in per unit. Hence this is a value close to one.
step
The tap step.
x
The series reactance deviation in percent of nominal value. The actual reactance is calculated as follows:
calculated reactance = x(nominal) * (1 + x(from this class)/100). The x(nominal) is defined as the static series reactance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
TransformerEnd
A conducting connection point of a power transformer. It corresponds to a physical transformer winding terminal. In earlier CIM versions, the TransformerWinding class served a similar purpose, but this class is more flexible because it associates to terminal but is not a specialization of ConductingEquipment.
endNumber
Number for this transformer end, corresponding to the end's order in the power transformer vector group or phase angle clock number. Highest voltage winding should be 1. Each end within a power transformer should have a unique subsequent end number. Note the transformer end number need not match the terminal sequence number.
LoadModel
This package is responsible for modeling the energy consumers and the system load as curves and associated curve data. Special circumstances that may affect the load, such as seasons and daytypes, are also included here.
This information is used by Load Forecasting and Load Management.
ConformLoad
ConformLoad represent loads that follow a daily load change pattern where the pattern can be used to scale the load with a system load.
EnergyConsumers
Conform loads assigned to this ConformLoadGroup.
No
LoadGroup
Group of this ConformLoad.
Yes
ConformLoadGroup
A group of loads conforming to an allocation pattern.
ConformLoadSchedules
The ConformLoadSchedules in the ConformLoadGroup.
No
ConformLoadGroup
The ConformLoadGroup where the ConformLoadSchedule belongs.
Yes
ConformLoadSchedule
A curve of load versus time (X-axis) showing the active power values (Y1-axis) and reactive power (Y2-axis) for each unit of the period covered. This curve represents a typical pattern of load over the time period for a given day type and season.
LoadGroup
The class is the third level in a hierarchical structure for grouping of loads for the purpose of load flow load scaling.
LoadResponseCharacteristic
Models the characteristic response of the load demand due to changes in system conditions such as voltage and frequency. This is not related to demand response.
If LoadResponseCharacteristic.exponentModel is True, the voltage exponents are specified and used as to calculate:
Active power component = Pnominal * (Voltage/cim:BaseVoltage.nominalVoltage) ** cim:LoadResponseCharacteristic.pVoltageExponent
Reactive power component = Qnominal * (Voltage/cim:BaseVoltage.nominalVoltage)** cim:LoadResponseCharacteristic.qVoltageExponent
Where * means "multiply" and ** is "raised to power of".
exponentModel
Indicates the exponential voltage dependency model is to be used. If false, the coefficient model is to be used.
The exponential voltage dependency model consist of the attributes
- pVoltageExponent
- qVoltageExponent.
The coefficient model consist of the attributes
- pConstantImpedance
- pConstantCurrent
- pConstantPower
- qConstantImpedance
- qConstantCurrent
- qConstantPower.
The sum of pConstantImpedance, pConstantCurrent and pConstantPower shall equal 1.
The sum of qConstantImpedance, qConstantCurrent and qConstantPower shall equal 1.
pConstantCurrent
Portion of active power load modeled as constant current.
pConstantImpedance
Portion of active power load modeled as constant impedance.
pConstantPower
Portion of active power load modeled as constant power.
pFrequencyExponent
Exponent of per unit frequency effecting active power.
pVoltageExponent
Exponent of per unit voltage effecting real power.
qConstantCurrent
Portion of reactive power load modeled as constant current.
qConstantImpedance
Portion of reactive power load modeled as constant impedance.
qConstantPower
Portion of reactive power load modeled as constant power.
qFrequencyExponent
Exponent of per unit frequency effecting reactive power.
qVoltageExponent
Exponent of per unit voltage effecting reactive power.
NonConformLoad
NonConformLoad represent loads that do not follow a daily load change pattern and changes are not correlated with the daily load change pattern.
LoadGroup
Conform loads assigned to this ConformLoadGroup.
Yes
EnergyConsumers
Group of this ConformLoad.
No
NonConformLoadGroup
Loads that do not follow a daily and seasonal load variation pattern.
NonConformLoadSchedules
The NonConformLoadSchedules in the NonConformLoadGroup.
No
NonConformLoadGroup
The NonConformLoadGroup where the NonConformLoadSchedule belongs.
Yes
NonConformLoadSchedule
An active power (Y1-axis) and reactive power (Y2-axis) schedule (curves) versus time (X-axis) for non-conforming loads, e.g., large industrial load or power station service (where modeled).
MonthDay
MonthDay format as "--mm-dd", which conforms with XSD data type gMonthDay.
Primitive
Equivalents
The equivalents package models equivalent networks.
EquivalentBranch
The class represents equivalent branches.
r
Positive sequence series resistance of the reduced branch.
r21
Resistance from terminal sequence 2 to terminal sequence 1 .Used for steady state power flow. This attribute is optional and represent unbalanced network such as off-nominal phase shifter. If only EquivalentBranch.r is given, then EquivalentBranch.r21 is assumed equal to EquivalentBranch.r.
Usage rule : EquivalentBranch is a result of network reduction prior to the data exchange.
x
Positive sequence series reactance of the reduced branch.
x21
Reactance from terminal sequence 2 to terminal sequence 1 .Used for steady state power flow. This attribute is optional and represent unbalanced network such as off-nominal phase shifter. If only EquivalentBranch.x is given, then EquivalentBranch.x21 is assumed equal to EquivalentBranch.x.
Usage rule : EquivalentBranch is a result of network reduction prior to the data exchange.
EquivalentEquipment
The class represents equivalent objects that are the result of a network reduction. The class is the base for equivalent objects of different types.
EquivalentEquipments
The equivalent where the reduced model belongs.
No
EquivalentNetwork
The associated reduced equivalents.
Yes
EquivalentInjection
This class represents equivalent injections (generation or load). Voltage regulation is allowed only at the point of connection.
maxP
Maximum active power of the injection.
maxQ
Used for modeling of infeed for load flow exchange. Not used for short circuit modeling. If maxQ and minQ are not used ReactiveCapabilityCurve can be used.
minP
Minimum active power of the injection.
minQ
Used for modeling of infeed for load flow exchange. Not used for short circuit modeling. If maxQ and minQ are not used ReactiveCapabilityCurve can be used.
regulationCapability
Specifies whether or not the EquivalentInjection has the capability to regulate the local voltage.
EquivalentNetwork
A class that represents an external meshed network that has been reduced to an electrically equivalent model. The ConnectivityNodes contained in the equivalent are intended to reflect internal nodes of the equivalent. The boundary Connectivity nodes where the equivalent connects outside itself are NOT contained by the equivalent.
EquivalentShunt
The class represents equivalent shunts.
b
Positive sequence shunt susceptance.
g
Positive sequence shunt conductance.
ControlArea
The ControlArea package models area specifications which can be used for a variety of purposes. The package as a whole models potentially overlapping control area specifications for the purpose of actual generation control, load forecast area load capture, or powerflow based analysis.
ControlArea
A control area is a grouping of generating units and/or loads and a cutset of tie lines (as terminals) which may be used for a variety of purposes including automatic generation control, powerflow solution area interchange control specification, and input to load forecasting. Note that any number of overlapping control area specifications can be superimposed on the physical model.
type
The primary type of control area definition used to determine if this is used for automatic generation control, for planning interchange control, or other purposes. A control area specified with primary type of automatic generation control could still be forecast and used as an interchange area in power flow analysis.
ControlAreaTypeKind
The type of control area.
AGC
Used for automatic generation control.
Forecast
Used for load forecast.
Interchange
Used for interchange specification or control.
ControlArea
The control area of the tie flows.
Yes
TieFlow
The tie flows associated with the control area.
No
ControlArea
The parent control area for the generating unit specifications.
Yes
ControlAreaGeneratingUnit
The generating unit specificaitons for the control area.
No
ControlAreaGeneratingUnit
A control area generating unit. This class is needed so that alternate control area definitions may include the same generating unit. Note only one instance within a control area should reference a specific generating unit.
TieFlow
A flow specification in terms of location and direction for a control area.
positiveFlowIn
True if the flow into the terminal (load convention) is also flow into the control area. For example, this attribute should be true if using the tie line terminal further away from the control area. For example to represent a tie to a shunt component (like a load or generator) in another area, this is the near end of a branch and this attribute would be specified as false.
PK ! 9ک g cimpyorm/res/schemata/CIM16/EquipmentProfileCoreShortCircuitOperationRDFSAugmented-v2_4_15-4Jul2016.rdf
EquipmentProfile
This profile has been built on the basis of the IEC 61970-452 document and adjusted to fit the purpose of the ENTSO-E CGMES.
EquipmentVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURIcore
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
baseURIoperation
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
baseURIshortCircuit
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURIcore
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentCore/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIoperation
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentOperation/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIshortCircuit
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentShortCircuit/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
DC
ACDCConverter
A unit with valves for three phases, together with unit control equipment, essential protective and switching devices, DC storage capacitors, phase reactors and auxiliaries, if any, used for conversion.
baseS
Base apparent power of the converter pole.
ApparentPower
Product of the RMS value of the voltage and the RMS value of the current.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
idleLoss
Active power loss in pole at no power transfer. Converter configuration data used in power flow.
ActivePower
Product of RMS value of the voltage and the RMS value of the in-phase component of the current.
CIMDatatype
value
unit
multiplier
maxUdc
The maximum voltage on the DC side at which the converter should operate. Converter configuration data used in power flow.
Voltage
Electrical voltage, can be both AC and DC.
CIMDatatype
value
unit
multiplier
minUdc
Min allowed converter DC voltage. Converter configuration data used in power flow.
numberOfValves
Number of valves in the converter. Used in loss calculations.
Integer
An integer number. The range is unspecified and not limited.
Primitive
ratedUdc
Rated converter DC voltage, also called UdN. Converter configuration data used in power flow.
resistiveLoss
Converter configuration data used in power flow. Refer to poleLossP.
Resistance
Resistance (real part of impedance).
CIMDatatype
value
unit
multiplier
switchingLoss
Switching losses, relative to the base apparent power 'baseS'.
Refer to poleLossP.
ActivePowerPerCurrentFlow
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
valveU0
Valve threshold voltage. Forward voltage drop when the valve is conducting. Used in loss calculations, i.e. the switchLoss depend on numberOfValves * valveU0.
DCConductingEquipment
Yes
DCTerminals
No
ConverterDCSides
Point of common coupling terminal for this converter DC side. It is typically the terminal on the power transformer (or switch) closest to the AC network. The power flow measurement must be the sum of all flows into the transformer.
No
PccTerminal
All converters' DC sides linked to this point of common coupling terminal.
Yes
ACDCConverterDCTerminal
A DC electrical connection point at the AC/DC converter. The AC/DC converter is electrically connected also to the AC side. The AC connection is inherited from the AC conducting equipment in the same way as any other AC equipment. The AC/DC converter DC terminal is separate from generic DC terminal to restrict the connection with the AC side to AC/DC converter and so that no other DC conducting equipment can be connected to the AC side.
polarity
Represents the normal network polarity condition.
DCPolarityKind
Polarity for DC circuits.
positive
Positive pole.
middle
Middle pole, potentially grounded.
negative
Negative pole.
CsConverter
DC side of the current source converter (CSC).
maxAlpha
Maximum firing angle. CSC configuration data used in power flow.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
multiplier
maxGamma
Maximum extinction angle. CSC configuration data used in power flow.
maxIdc
The maximum direct current (Id) on the DC side at which the converter should operate. Converter configuration data use in power flow.
CurrentFlow
Electrical current with sign convention: positive flow is out of the conducting equipment into the connectivity node. Can be both AC and DC.
CIMDatatype
value
unit
multiplier
minAlpha
Minimum firing angle. CSC configuration data used in power flow.
minGamma
Minimum extinction angle. CSC configuration data used in power flow.
minIdc
The minimum direct current (Id) on the DC side at which the converter should operate. CSC configuration data used in power flow.
ratedIdc
Rated converter DC current, also called IdN. Converter configuration data used in power flow.
DCBaseTerminal
An electrical connection point at a piece of DC conducting equipment. DC terminals are connected at one physical DC node that may have multiple DC terminals connected. A DC node is similar to an AC connectivity node. The model enforces that DC connections are distinct from AC connections.
DCTerminals
No
DCNode
Yes
DCBreaker
A breaker within a DC system.
DCBusbar
A busbar within a DC system.
DCChopper
Low resistance equipment used in the internal DC circuit to balance voltages. It has typically positive and negative pole terminals and a ground.
DCConductingEquipment
The parts of the DC power system that are designed to carry current or that are conductively connected through DC terminals.
DCTerminals
No
DCConductingEquipment
Yes
DCConverterOperatingModeKind
The operating mode of an HVDC bipole.
bipolar
Bipolar operation.
monopolarMetallicReturn
Monopolar operation with metallic return
monopolarGroundReturn
Monopolar operation with ground return
DCConverterUnit
Indivisible operative unit comprising all equipment between the point of common coupling on the AC side and the point of common coupling – DC side, essentially one or more converters, together with one or more converter transformers, converter control equipment, essential protective and switching devices and auxiliaries, if any, used for conversion.
operationMode
Substation
Yes
DCConverterUnit
No
DCDisconnector
A disconnector within a DC system.
DCEquipmentContainer
A modeling construct to provide a root class for containment of DC as well as AC equipment. The class differ from the EquipmentContaner for AC in that it may also contain DCNodes. Hence it can contain both AC and DC equipment.
DCEquipmentContainer
Yes
DCNodes
No
DCGround
A ground within a DC system.
inductance
Inductance to ground.
Inductance
Inductive part of reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
r
Resistance to ground.
DCLine
Overhead lines and/or cables connecting two or more HVDC substations.
Region
Yes
DCLines
No
DCLineSegment
A wire or combination of wires not insulated from one another, with consistent electrical characteristics, used to carry direct current between points in the DC region of the power system.
capacitance
Capacitance of the DC line segment. Significant for cables only.
Capacitance
Capacitive part of reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
inductance
Inductance of the DC line segment. Neglectable compared with DCSeriesDevice used for smoothing.
resistance
Resistance of the DC line segment.
length
Segment length for calculating line section capabilities.
Length
Unit of length. Never negative.
CIMDatatype
value
unit
multiplier
DCLineSegments
All line segments described by this set of per-length parameters.
No
PerLengthParameter
Set of per-length parameters for this line segment.
Yes
DCNode
DC nodes are points where terminals of DC conducting equipment are connected together with zero impedance.
DCSeriesDevice
A series device within the DC system, typically a reactor used for filtering or smoothing. Needed for transient and short circuit studies.
inductance
Inductance of the device.
resistance
Resistance of the DC device.
ratedUdc
Rated DC device voltage. Converter configuration data used in power flow.
DCShunt
A shunt device within the DC system, typically used for filtering. Needed for transient and short circuit studies.
capacitance
Capacitance of the DC shunt.
resistance
Resistance of the DC device.
ratedUdc
Rated DC device voltage. Converter configuration data used in power flow.
DCSwitch
A switch within the DC system.
DCTerminal
An electrical connection point to generic DC conducting equipment.
PerLengthDCLineParameter
capacitance
Capacitance per unit of length of the DC line segment; significant for cables only.
CapacitancePerLength
Capacitance per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
inductance
Inductance per unit of length of the DC line segment.
InductancePerLength
Inductance per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
resistance
Resistance per length of the DC line segment.
ResistancePerLength
Resistance (real part of impedance) per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
VsCapabilityCurve
The P-Q capability curve for a voltage source converter, with P on x-axis and Qmin and Qmax on y1-axis and y2-axis.
VsConverterDCSides
Capability curve of this converter.
No
CapabilityCurve
All converters with this capability curve.
Yes
VsConverter
DC side of the voltage source converter (VSC).
maxModulationIndex
The max quotient between the AC converter voltage (Uc) and DC voltage (Ud). A factor typically less than 1. VSC configuration data used in power flow.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
maxValveCurrent
The maximum current through a valve. This current limit is the basis for calculating the capability diagram. VSC configuration data.
Topology
BusNameMarker
Used to apply user standard names to topology buses. Typically used for "bus/branch" case generation. Associated with one or more terminals that are normally connected with the bus name. The associated terminals are normally connected by non-retained switches. For a ring bus station configuration, all busbar terminals in the ring are typically associated. For a breaker and a half scheme, both busbars would normally be associated. For a ring bus, all busbars would normally be associated. For a "straight" busbar configuration, normally only the main terminal at the busbar would be associated.
priority
Priority of bus name marker for use as topology bus name. Use 0 for don t care. Use 1 for highest priority. Use 2 as priority is less than 1 and so on.
BusNameMarker
The reporting group to which this bus name marker belongs.
No
ReportingGroup
The bus name markers that belong to this reporting group.
Yes
Terminal
The terminals associated with this bus name marker.
No
BusNameMarker
The bus name marker used to name the bus (topological node).
Yes
Meas
Accumulator
Accumulator represents an accumulated (counted) Measurement, e.g. an energy value.
Operation
Measurements
A measurement may have zero or more limit ranges defined for it.
Yes
LimitSets
The Measurements using the LimitSet.
No
Accumulator
The values connected to this measurement.
Yes
AccumulatorValues
Measurement to which this value is connected.
No
AccumulatorLimit
Limit values for Accumulator measurements.
Operation
value
The value to supervise against. The value is positive.
LimitSet
The limit values used for supervision of Measurements.
Yes
Limits
The set of limits.
No
AccumulatorLimitSet
An AccumulatorLimitSet specifies a set of Limits that are associated with an Accumulator measurement.
Operation
AccumulatorReset
This command reset the counter value to zero.
Operation
AccumulatorValue
The accumulator value that is reset by the command.
Yes
AccumulatorReset
The command that reset the accumulator value.
No
AccumulatorValue
AccumulatorValue represents an accumulated (counted) MeasurementValue.
Operation
value
The value to supervise. The value is positive.
Analog
Analog represents an analog Measurement.
Operation
positiveFlowIn
If true then this measurement is an active power, reactive power or current with the convention that a positive value measured at the Terminal means power is flowing into the related PowerSystemResource.
Boolean
A type with the value space "true" and "false".
Primitive
Analog
The values connected to this measurement.
Yes
AnalogValues
Measurement to which this value is connected.
No
Measurements
A measurement may have zero or more limit ranges defined for it.
Yes
LimitSets
The Measurements using the LimitSet.
No
AnalogControl
An analog control used for supervisory control.
Operation
maxValue
Normal value range maximum for any of the Control.value. Used for scaling, e.g. in bar graphs.
minValue
Normal value range minimum for any of the Control.value. Used for scaling, e.g. in bar graphs.
AnalogValue
The Control variable associated with the MeasurementValue.
Yes
AnalogControl
The MeasurementValue that is controlled.
No
AnalogLimit
Limit values for Analog measurements.
Operation
value
The value to supervise against.
LimitSet
The limit values used for supervision of Measurements.
Yes
Limits
The set of limits.
No
AnalogLimitSet
An AnalogLimitSet specifies a set of Limits that are associated with an Analog measurement.
Operation
AnalogValue
AnalogValue represents an analog MeasurementValue.
Operation
value
The value to supervise.
Command
A Command is a discrete control used for supervisory control.
Operation
normalValue
Normal value for Control.value e.g. used for percentage scaling.
value
The value representing the actuator output.
DiscreteValue
The Control variable associated with the MeasurementValue.
Yes
Command
The MeasurementValue that is controlled.
No
ValueAliasSet
The ValueAliasSet used for translation of a Control value to a name.
Yes
Commands
The Commands using the set for translation.
No
Control
Control is used for supervisory/device control. It represents control outputs that are used to change the state in a process, e.g. close or open breaker, a set point value or a raise lower command.
Operation
controlType
Specifies the type of Control, e.g. BreakerOn/Off, GeneratorVoltageSetPoint, TieLineFlow etc. The ControlType.name shall be unique among all specified types and describe the type.
operationInProgress
Indicates that a client is currently sending control commands that has not completed.
timeStamp
The last time a control output was sent.
DateTime
Date and time as "yyyy-mm-ddThh:mm:ss.sss", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddThh:mm:ss.sssZ". A local timezone relative UTC is specified as "yyyy-mm-ddThh:mm:ss.sss-hh:mm". The second component (shown here as "ss.sss") could have any number of digits in its fractional part to allow any kind of precision beyond seconds.
Primitive
unitMultiplier
The unit multiplier of the controlled quantity.
unitSymbol
The unit of measure of the controlled quantity.
PowerSystemResource
The controller outputs used to actually govern a regulating device, e.g. the magnetization of a synchronous machine or capacitor bank breaker actuator.
Yes
Controls
Regulating device governed by this control output.
No
Discrete
Discrete represents a discrete Measurement, i.e. a Measurement representing discrete values, e.g. a Breaker position.
Operation
Discrete
The values connected to this measurement.
Yes
DiscreteValues
Measurement to which this value is connected.
No
Discretes
The Measurements using the set for translation.
No
ValueAliasSet
The ValueAliasSet used for translation of a MeasurementValue.value to a name.
Yes
DiscreteValue
DiscreteValue represents a discrete MeasurementValue.
Operation
value
The value to supervise.
Limit
Specifies one limit value for a Measurement. A Measurement typically has several limits that are kept together by the LimitSet class. The actual meaning and use of a Limit instance (i.e., if it is an alarm or warning limit or if it is a high or low limit) is not captured in the Limit class. However the name of a Limit instance may indicate both meaning and use.
Operation
LimitSet
Specifies a set of Limits that are associated with a Measurement. A Measurement may have several LimitSets corresponding to seasonal or other changing conditions. The condition is captured in the name and description attributes. The same LimitSet may be used for several Measurements. In particular percentage limits are used this way.
Operation
isPercentageLimits
Tells if the limit values are in percentage of normalValue or the specified Unit for Measurements and Controls.
Measurement
A Measurement represents any measured, calculated or non-measured non-calculated quantity. Any piece of equipment may contain Measurements, e.g. a substation may have temperature measurements and door open indications, a transformer may have oil temperature and tank pressure measurements, a bay may contain a number of power flow measurements and a Breaker may contain a switch status measurement.
The PSR - Measurement association is intended to capture this use of Measurement and is included in the naming hierarchy based on EquipmentContainer. The naming hierarchy typically has Measurements as leafs, e.g. Substation-VoltageLevel-Bay-Switch-Measurement.
Some Measurements represent quantities related to a particular sensor location in the network, e.g. a voltage transformer (PT) at a busbar or a current transformer (CT) at the bar between a breaker and an isolator. The sensing position is not captured in the PSR - Measurement association. Instead it is captured by the Measurement - Terminal association that is used to define the sensing location in the network topology. The location is defined by the connection of the Terminal to ConductingEquipment.
If both a Terminal and PSR are associated, and the PSR is of type ConductingEquipment, the associated Terminal should belong to that ConductingEquipment instance.
When the sensor location is needed both Measurement-PSR and Measurement-Terminal are used. The Measurement-Terminal association is never used alone.
Operation
measurementType
Specifies the type of measurement. For example, this specifies if the measurement represents an indoor temperature, outdoor temperature, bus voltage, line flow, etc.
phases
Indicates to which phases the measurement applies and avoids the need to use 'measurementType' to also encode phase information (which would explode the types). The phase information in Measurement, along with 'measurementType' and 'phases' uniquely defines a Measurement for a device, based on normal network phase. Their meaning will not change when the computed energizing phasing is changed due to jumpers or other reasons.
If the attribute is missing three phases (ABC) shall be assumed.
PhaseCode
Enumeration of phase identifiers. Allows designation of phases for both transmission and distribution equipment, circuits and loads.
Residential and small commercial loads are often served from single-phase, or split-phase, secondary circuits. For example of s12N, phases 1 and 2 refer to hot wires that are 180 degrees out of phase, while N refers to the neutral wire. Through single-phase transformer connections, these secondary circuits may be served from one or two of the primary phases A, B, and C. For three-phase loads, use the A, B, C phase codes instead of s12N.
ABCN
Phases A, B, C, and N.
ABC
Phases A, B, and C.
ABN
Phases A, B, and neutral.
ACN
Phases A, C and neutral.
BCN
Phases B, C, and neutral.
AB
Phases A and B.
AC
Phases A and C.
BC
Phases B and C.
AN
Phases A and neutral.
BN
Phases B and neutral.
CN
Phases C and neutral.
A
Phase A.
B
Phase B.
C
Phase C.
N
Neutral phase.
s1N
Secondary phase 1 and neutral.
s2N
Secondary phase 2 and neutral.
s12N
Secondary phases 1, 2, and neutral.
s1
Secondary phase 1.
s2
Secondary phase 2.
s12
Secondary phase 1 and 2.
unitSymbol
The unit of measure of the measured quantity.
unitMultiplier
The unit multiplier of the measured quantity.
Terminal
One or more measurements may be associated with a terminal in the network.
Yes
Measurements
Measurements associated with this terminal defining where the measurement is placed in the network topology. It may be used, for instance, to capture the sensor position, such as a voltage transformer (PT) at a busbar or a current transformer (CT) at the bar between a breaker and an isolator.
No
PowerSystemResource
The measurements associated with this power system resource.
Yes
Measurements
The power system resource that contains the measurement.
No
MeasurementValue
The current state for a measurement. A state value is an instance of a measurement from a specific source. Measurements can be associated with many state values, each representing a different source for the measurement.
Operation
timeStamp
The time when the value was last updated
sensorAccuracy
The limit, expressed as a percentage of the sensor maximum, that errors will not exceed when the sensor is used under reference conditions.
PerCent
Percentage on a defined base. For example, specify as 100 to indicate at the defined base.
CIMDatatype
value
Normally 0 - 100 on a defined base
unit
multiplier
MeasurementValue
A MeasurementValue has a MeasurementValueQuality associated with it.
Yes
MeasurementValueQuality
A MeasurementValue has a MeasurementValueQuality associated with it.
No
MeasurementValueSource
The MeasurementValues updated by the source.
Yes
MeasurementValues
A reference to the type of source that updates the MeasurementValue, e.g. SCADA, CCLink, manual, etc. User conventions for the names of sources are contained in the introduction to IEC 61970-301.
No
MeasurementValueQuality
Measurement quality flags. Bits 0-10 are defined for substation automation in draft IEC 61850 part 7-3. Bits 11-15 are reserved for future expansion by that document. Bits 16-31 are reserved for EMS applications.
Operation
MeasurementValueSource
MeasurementValueSource describes the alternative sources updating a MeasurementValue. User conventions for how to use the MeasurementValueSource attributes are described in the introduction to IEC 61970-301.
Operation
Quality61850
Quality flags in this class are as defined in IEC 61850, except for estimatorReplaced, which has been included in this class for convenience.
Operation
badReference
Measurement value may be incorrect due to a reference being out of calibration.
estimatorReplaced
Value has been replaced by State Estimator. estimatorReplaced is not an IEC61850 quality bit but has been put in this class for convenience.
failure
This identifier indicates that a supervision function has detected an internal or external failure, e.g. communication failure.
oldData
Measurement value is old and possibly invalid, as it has not been successfully updated during a specified time interval.
operatorBlocked
Measurement value is blocked and hence unavailable for transmission.
oscillatory
To prevent some overload of the communication it is sensible to detect and suppress oscillating (fast changing) binary inputs. If a signal changes in a defined time (tosc) twice in the same direction (from 0 to 1 or from 1 to 0) then oscillation is detected and the detail quality identifier "oscillatory" is set. If it is detected a configured numbers of transient changes could be passed by. In this time the validity status "questionable" is set. If after this defined numbers of changes the signal is still in the oscillating state the value shall be set either to the opposite state of the previous stable value or to a defined default value. In this case the validity status "questionable" is reset and "invalid" is set as long as the signal is oscillating. If it is configured such that no transient changes should be passed by then the validity status "invalid" is set immediately in addition to the detail quality identifier "oscillatory" (used for status information only).
outOfRange
Measurement value is beyond a predefined range of value.
overFlow
Measurement value is beyond the capability of being represented properly. For example, a counter value overflows from maximum count back to a value of zero.
source
Source gives information related to the origin of a value. The value may be acquired from the process, defaulted or substituted.
Source
Source gives information related to the origin of a value.
PROCESS
The value is provided by input from the process I/O or being calculated from some function.
DEFAULTED
The value contains a default value.
SUBSTITUTED
The value is provided by input of an operator or by an automatic source.
suspect
A correlation function has detected that the value is not consitent with other values. Typically set by a network State Estimator.
test
Measurement value is transmitted for test purposes.
validity
Validity of the measurement value.
Validity
Validity for MeasurementValue.
GOOD
The value is marked good if no abnormal condition of the acquisition function or the information source is detected.
QUESTIONABLE
The value is marked questionable if a supervision function detects an abnormal behaviour, however the value could still be valid. The client is responsible for determining whether or not values marked "questionable" should be used.
INVALID
The value is marked invalid when a supervision function recognises abnormal conditions of the acquisition function or the information source (missing or non-operating updating devices). The value is not defined under this condition. The mark invalid is used to indicate to the client that the value may be incorrect and shall not be used.
RaiseLowerCommand
An analog control that increase or decrease a set point value with pulses.
Operation
ValueAliasSet
The ValueAliasSet used for translation of a Control value to a name.
Yes
RaiseLowerCommands
The Commands using the set for translation.
No
SetPoint
An analog control that issue a set point value.
Operation
normalValue
Normal value for Control.value e.g. used for percentage scaling.
value
The value representing the actuator output.
StringMeasurement
StringMeasurement represents a measurement with values of type string.
Operation
StringMeasurement
Measurement to which this value is connected.
Yes
StringMeasurementValues
The values connected to this measurement.
No
StringMeasurementValue
StringMeasurementValue represents a measurement value of type string.
Operation
value
The value to supervise.
ValueAliasSet
Describes the translation of a set of values into a name and is intendend to facilitate cusom translations. Each ValueAliasSet has a name, description etc. A specific Measurement may represent a discrete state like Open, Closed, Intermediate etc. This requires a translation from the MeasurementValue.value number to a string, e.g. 0->"Invalid", 1->"Open", 2->"Closed", 3->"Intermediate". Each ValueToAlias member in ValueAliasSet.Value describe a mapping for one particular value to a name.
Operation
ValueAliasSet
The ValueToAlias mappings included in the set.
Yes
Values
The ValueAliasSet having the ValueToAlias mappings.
No
ValueToAlias
Describes the translation of one particular value into a name, e.g. 1 as "Open".
Operation
value
The value that is mapped.
Production
The production package is responsible for classes which describe various kinds of generators. These classes also provide production costing information which is used to economically allocate demand among committed units and calculate reserve quantities.
EnergySchedulingType
Used to define the type of generation for scheduling purposes.
Entsoe
EnergySource
Energy Scheduling Type of an Energy Source
No
EnergySchedulingType
Energy Source of a particular Energy Scheduling Type
Yes
EnergySource
A generic equivalent for an energy supplier on a transmission or distribution voltage level.
nominalVoltage
Phase-to-phase nominal voltage.
r
Positive sequence Thevenin resistance.
r0
Zero sequence Thevenin resistance.
rn
Negative sequence Thevenin resistance.
voltageAngle
Phase angle of a-phase open circuit.
AngleRadians
Phase angle in radians.
CIMDatatype
value
unit
multiplier
voltageMagnitude
Phase-to-phase open circuit voltage magnitude.
x
Positive sequence Thevenin reactance.
Reactance
Reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
x0
Zero sequence Thevenin reactance.
xn
Negative sequence Thevenin reactance.
FossilFuel
The fossil fuel consumed by the non-nuclear thermal generating unit. For example, coal, oil, gas, etc. This a the specific fuels that the generating unit can consume.
fossilFuelType
The type of fossil fuel, such as coal, oil, or gas.
FuelType
Type of fuel.
coal
Generic coal, not including lignite type.
oil
Oil.
gas
Natural gas.
lignite
The fuel is lignite coal. Note that this is a special type of coal, so the other enum of coal is reserved for hard coal types or if the exact type of coal is not known.
hardCoal
Hard coal
oilShale
Oil Shale
FossilFuels
A thermal generating unit may have one or more fossil fuels.
No
ThermalGeneratingUnit
A thermal generating unit may have one or more fossil fuels.
Yes
GeneratingUnit
A single or set of synchronous machines for converting mechanical power into alternating-current power. For example, individual machines within a set may be defined for scheduling purposes while a single control signal is derived for the set. In this case there would be a GeneratingUnit for each member of the set and an additional GeneratingUnit corresponding to the set.
genControlSource
The source of controls for a generating unit.
GeneratorControlSource
The source of controls for a generating unit.
unavailable
Not available.
offAGC
Off of automatic generation control (AGC).
onAGC
On automatic generation control (AGC).
plantControl
Plant is controlling.
governorSCD
Governor Speed Changer Droop. This is the change in generator power output divided by the change in frequency normalized by the nominal power of the generator and the nominal frequency and expressed in percent and negated. A positive value of speed change droop provides additional generator output upon a drop in frequency.
initialP
Default initial active power which is used to store a powerflow result for the initial active power for this unit in this network configuration.
longPF
Generating unit long term economic participation factor.
maximumAllowableSpinningReserve
Maximum allowable spinning reserve. Spinning reserve will never be considered greater than this value regardless of the current operating point.
maxOperatingP
This is the maximum operating active power limit the dispatcher can enter for this unit.
minOperatingP
This is the minimum operating active power limit the dispatcher can enter for this unit.
nominalP
The nominal power of the generating unit. Used to give precise meaning to percentage based attributes such as the governor speed change droop (governorSCD attribute).
The attribute shall be a positive value equal or less than RotatingMachine.ratedS.
ratedGrossMaxP
The unit's gross rated maximum capacity (book value).
ratedGrossMinP
The gross rated minimum generation level which the unit can safely operate at while delivering power to the transmission grid.
ratedNetMaxP
The net rated maximum capacity determined by subtracting the auxiliary power used to operate the internal plant machinery from the rated gross maximum capacity.
shortPF
Generating unit short term economic participation factor.
startupCost
The initial startup cost incurred for each start of the GeneratingUnit.
Money
Amount of money.
CIMDatatype
unit
Currency
Monetary currencies. Apologies for this list not being exhaustive.
USD
US dollar
EUR
European euro
AUD
Australian dollar
CAD
Canadian dollar
CHF
Swiss francs
CNY
Chinese yuan renminbi
DKK
Danish crown
GBP
British pound
JPY
Japanese yen
NOK
Norwegian crown
RUR
Russian ruble
SEK
Swedish crown
INR
India rupees
other
Another type of currency.
multiplier
value
Decimal
Decimal is the base-10 notational system for representing real numbers.
Primitive
variableCost
The variable cost component of production per unit of ActivePower.
totalEfficiency
The efficiency of the unit in converting the fuel into electrical energy.
GeneratingUnit
The generating unit specified for this control area. Note that a control area should include a GeneratingUnit only once.
Yes
ControlAreaGeneratingUnit
ControlArea specifications for this generating unit.
No
GeneratingUnit
A synchronous machine may operate as a generator and as such becomes a member of a generating unit.
Yes
RotatingMachine
A synchronous machine may operate as a generator and as such becomes a member of a generating unit.
No
GeneratingUnit
A generating unit may have a gross active power to net active power curve, describing the losses and auxiliary power requirements of the unit.
Yes
GrossToNetActivePowerCurves
A generating unit may have a gross active power to net active power curve, describing the losses and auxiliary power requirements of the unit.
No
GrossToNetActivePowerCurve
Relationship between the generating unit's gross active power output on the X-axis (measured at the terminals of the machine(s)) and the generating unit's net active power output on the Y-axis (based on utility-defined measurements at the power station). Station service loads, when modeled, should be treated as non-conforming bus loads. There may be more than one curve, depending on the auxiliary equipment that is in service.
Operation
HydroEnergyConversionKind
Specifies the capability of the hydro generating unit to convert energy as a generator or pump.
generator
Able to generate power, but not able to pump water for energy storage.
pumpAndGenerator
Able to both generate power and pump water for energy storage.
HydroGeneratingUnit
A generating unit whose prime mover is a hydraulic turbine (e.g., Francis, Pelton, Kaplan).
energyConversionCapability
Energy conversion capability for generating.
HydroGeneratingUnits
The hydro generating unit belongs to a hydro power plant.
No
HydroPowerPlant
The hydro generating unit belongs to a hydro power plant.
Yes
HydroPlantStorageKind
The type of hydro power plant.
runOfRiver
Run of river.
pumpedStorage
Pumped storage.
storage
Storage.
HydroPowerPlant
A hydro power station which can generate or pump. When generating, the generator turbines receive water from an upper reservoir. When pumping, the pumps receive their water from a lower reservoir.
hydroPlantStorageType
The type of hydro power plant water storage.
HydroPumps
The hydro pump may be a member of a pumped storage plant or a pump for distributing water.
No
HydroPowerPlant
The hydro pump may be a member of a pumped storage plant or a pump for distributing water.
Yes
HydroPump
A synchronous motor-driven pump, typically associated with a pumped storage plant.
RotatingMachine
The synchronous machine drives the turbine which moves the water from a low elevation to a higher elevation. The direction of machine rotation for pumping may or may not be the same as for generating.
Yes
HydroPump
The synchronous machine drives the turbine which moves the water from a low elevation to a higher elevation. The direction of machine rotation for pumping may or may not be the same as for generating.
No
NuclearGeneratingUnit
A nuclear generating unit.
SolarGeneratingUnit
A solar thermal generating unit.
ThermalGeneratingUnit
A generating unit whose prime mover could be a steam turbine, combustion turbine, or diesel engine.
WindGeneratingUnit
A wind driven generating unit. May be used to represent a single turbine or an aggregation.
windGenUnitType
The kind of wind generating unit
WindGenUnitKind
Kind of wind generating unit.
offshore
The wind generating unit is located offshore.
onshore
The wind generating unit is located onshore.
Core
Contains the core PowerSystemResource and ConductingEquipment entities shared by all applications plus common collections of those entities. Not all applications require all the Core entities. This package does not depend on any other package except the Domain package, but most of the other packages have associations and generalizations that depend on it.
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
sequenceNumber
The orientation of the terminal connections for a multiple terminal conducting equipment. The sequence numbering starts with 1 and additional terminals should follow in increasing order. The first terminal is the "starting point" for a two terminal branch.
Terminal
Yes
OperationalLimitSet
No
BaseVoltage
Defines a system base voltage which is referenced.
nominalVoltage
The power system resource's base voltage.
BaseVoltage
All conducting equipment with this base voltage. Use only when there is no voltage level container used and only one base voltage applies. For example, not used for transformers.
Yes
ConductingEquipment
Base voltage of this conducting equipment. Use only when there is no voltage level container used and only one base voltage applies. For example, not used for transformers.
No
BaseVoltage
The base voltage used for all equipment within the voltage level.
Yes
VoltageLevel
The voltage levels having this base voltage.
No
BaseVoltage
Base voltage of the transformer end. This is essential for PU calculation.
Yes
TransformerEnds
Transformer ends at the base voltage. This is essential for PU calculation.
No
BasicIntervalSchedule
Schedule of values at points in time.
startTime
The time for the first time point.
value1Unit
Value1 units of measure.
value2Unit
Value2 units of measure.
Bay
A collection of power system resources (within a given substation) including conducting equipment, protection relays, measurements, and telemetry. A bay typically represents a physical grouping related to modularization of equipment.
Operation
Bays
The bays within this voltage level.
No
VoltageLevel
The voltage level containing this bay.
Yes
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
ConductingEquipment
The conducting equipment of the terminal. Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
Yes
Terminals
Conducting equipment have terminals that may be connected to other conducting equipment terminals via connectivity nodes or topological nodes.
No
ConnectivityNode
Connectivity nodes are points where terminals of AC conducting equipment are connected together with zero impedance.
Operation
Terminals
The connectivity node to which this terminal connects with zero impedance.
No
ConnectivityNode
Terminals interconnected with zero impedance at a this connectivity node.
Yes
ConnectivityNodeContainer
Container of this connectivity node.
Yes
ConnectivityNodes
Connectivity nodes which belong to this connectivity node container.
No
ConnectivityNodeContainer
A base class for all objects that may contain connectivity nodes or topological nodes.
Curve
A multi-purpose curve or functional relationship between an independent variable (X-axis) and dependent (Y-axis) variables.
curveStyle
The style or shape of the curve.
CurveStyle
Style or shape of curve.
constantYValue
The Y-axis values are assumed constant until the next curve point and prior to the first curve point.
straightLineYValues
The Y-axis values are assumed to be a straight line between values. Also known as linear interpolation.
xUnit
The X-axis units of measure.
y1Unit
The Y1-axis units of measure.
y2Unit
The Y2-axis units of measure.
CurveDatas
The curve of this curve data point.
No
Curve
The point data values that define this curve.
Yes
CurveData
Multi-purpose data points for defining a curve. The use of this generic class is discouraged if a more specific class can be used to specify the x and y axis values along with their specific data types.
xvalue
The data value of the X-axis variable, depending on the X-axis units.
y1value
The data value of the first Y-axis variable, depending on the Y-axis units.
y2value
The data value of the second Y-axis variable (if present), depending on the Y-axis units.
Equipment
The parts of a power system that are physical devices, electronic or mechanical.
aggregate
The single instance of equipment represents multiple pieces of equipment that have been modeled together as an aggregate. Examples would be power transformers or synchronous machines operating in parallel modeled as a single aggregate power transformer or aggregate synchronous machine. This is not to be used to indicate equipment that is part of a group of interdependent equipment produced by a network production program.
Equipments
Contained equipment.
No
EquipmentContainer
Container of this equipment.
Yes
Equipment
The equipment to which the limit set applies.
Yes
OperationalLimitSet
The operational limit sets associated with this equipment.
No
EquipmentContainer
A modeling construct to provide a root class for containing equipment.
GeographicalRegion
A geographical region of a power system network model.
Regions
All sub-geograhpical regions within this geographical region.
No
Region
The geographical region to which this sub-geographical region is within.
Yes
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
energyIdentCodeEic
Entsoe
The attribute is used for an exchange of the EIC code (Energy identification Code). The length of the string is 16 characters as defined by the EIC code.
References:
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
shortName
Entsoe
The attribute is used for an exchange of a human readable short name with length of the string 12 characters maximum.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
RegularIntervalSchedule
The schedule has time points where the time between them is constant.
timeStep
The time between each pair of subsequent regular time points in sequence order.
Seconds
Time, in seconds.
CIMDatatype
value
Time, in seconds
unit
multiplier
endTime
The time for the last time point.
TimePoints
The regular interval time point data values that define this schedule.
No
IntervalSchedule
Regular interval schedule containing this time point.
Yes
RegularTimePoint
Time point for a schedule where the time between the consecutive points is constant.
Operation
sequenceNumber
The position of the regular time point in the sequence. Note that time points don't have to be sequential, i.e. time points may be omitted. The actual time for a RegularTimePoint is computed by multiplying the associated regular interval schedule's time step with the regular time point sequence number and adding the associated schedules start time.
value1
The first value at the time. The meaning of the value is defined by the derived type of the associated schedule.
value2
The second value at the time. The meaning of the value is defined by the derived type of the associated schedule.
ReportingGroup
A reporting group is used for various ad-hoc groupings used for reporting.
SubGeographicalRegion
A subset of a geographical region of a power system network model.
Lines
The lines within the sub-geographical region.
No
Region
The sub-geographical region of the line.
Yes
Substations
The substations in this sub-geographical region.
No
Region
The SubGeographicalRegion containing the substation.
Yes
Substation
A collection of equipment for purposes other than generation or utilization, through which electric energy in bulk is passed for the purposes of switching or modifying its characteristics.
VoltageLevels
The voltage levels within this substation.
No
Substation
The substation of the voltage level.
Yes
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
phases
Represents the normal network phasing condition.
If the attribute is missing three phases (ABC or ABCN) shall be assumed.
First_Terminal
The starting terminal for the calculation of distances along the first branch of the mutual coupling. Normally MutualCoupling would only be used for terminals of AC line segments. The first and second terminals of a mutual coupling should point to different AC line segments.
Yes
HasFirstMutualCoupling
Mutual couplings associated with the branch as the first branch.
No
Second_Terminal
The starting terminal for the calculation of distances along the second branch of the mutual coupling.
Yes
HasSecondMutualCoupling
Mutual couplings with the branch associated as the first branch.
No
Terminal
The controls regulating this terminal.
Yes
RegulatingControl
The terminal associated with this regulating control. The terminal is associated instead of a node, since the terminal could connect into either a topological node (bus in bus-branch model) or a connectivity node (detailed switch model). Sometimes it is useful to model regulation at a terminal of a bus bar object since the bus bar can be present in both a bus-branch model or a model with switch detail.
No
Terminal
The terminal to which this tie flow belongs.
Yes
TieFlow
The control area tie flows to which this terminal associates.
No
Terminal
Terminal of the power transformer to which this transformer end belongs.
Yes
TransformerEnd
All transformer ends connected at this terminal.
No
VoltageLevel
A collection of equipment at one common system voltage forming a switchgear. The equipment typically consist of breakers, busbars, instrumentation, control, regulation and protection devices as well as assemblies of all these.
highVoltageLimit
The bus bar's high voltage limit
lowVoltageLimit
The bus bar's low voltage limit
OperationalLimits
The OperationalLimits package models a specification of limits associated with equipment and other operational entities.
ActivePowerLimit
Limit on active power flow.
Operation
value
Value of active power limit.
ApparentPowerLimit
Apparent power limit.
Operation
value
The apparent power limit.
CurrentLimit
Operational limit on current.
value
Limit on current flow.
LimitTypeKind
The enumeration defines the kinds of the limit types.
Entsoe
patl
The Permanent Admissible Transmission Loading (PATL) is the loading in Amps, MVA or MW that can be accepted by a network branch for an unlimited duration without any risk for the material.
The duration attribute is not used and shall be excluded for the PATL limit type. Hence only one limit value exists for the PATL type.
patlt
Permanent Admissible Transmission Loading Threshold (PATLT) is a value in engineering units defined for PATL and calculated using percentage less than 100 of the PATL type intended to alert operators of an arising condition. The percentage should be given in the name of the OperationalLimitSet. The aceptableDuration is another way to express the severity of the limit.
tatl
Temporarily Admissible Transmission Loading (TATL) which is the loading in Amps, MVA or MW that can be accepted by a branch for a certain limited duration.
The TATL can be defined in different ways:
- as a fixed percentage of the PATL for a given time (for example, 115% of the PATL that can be accepted during 15 minutes),
- pairs of TATL type and Duration calculated for each line taking into account its particular configuration and conditions of functioning (for example, it can define a TATL acceptable during 20 minutes and another one acceptable during 10 minutes).
Such a definition of TATL can depend on the initial operating conditions of the network element (sag situation of a line).
The duration attribute can be used define several TATL limit types. Hence multiple TATL limit values may exist having different durations.
tc
Tripping Current (TC) is the ultimate intensity without any delay. It is defined as the threshold the line will trip without any possible remedial actions.
The tripping of the network element is ordered by protections against short circuits or by overload protections, but in any case, the activation delay of these protections is not compatible with the reaction delay of an operator (less than one minute).
The duration is always zero and the duration attribute may be left out. Hence only one limit value exists for the TC type.
tct
Tripping Current Threshold (TCT) is a value in engineering units defined for TC and calculated using percentage less than 100 of the TC type intended to alert operators of an arising condition. The percentage should be given in the name of the OperationalLimitSet. The aceptableDuration is another way to express the severity of the limit.
highVoltage
Referring to the rating of the equipments, a voltage too high can lead to accelerated ageing or the destruction of the equipment.
This limit type may or may not have duration.
lowVoltage
A too low voltage can disturb the normal operation of some protections and transformer equipped with on-load tap changers, electronic power devices or can affect the behaviour of the auxiliaries of generation units.
This limit type may or may not have duration.
OperationalLimit
A value associated with a specific kind of limit.
The sub class value attribute shall be positive.
The sub class value attribute is inversely proportional to OperationalLimitType.acceptableDuration (acceptableDuration for short). A pair of value_x and acceptableDuration_x are related to each other as follows:
if value_1 > value_2 > value_3 >... then
acceptableDuration_1 < acceptableDuration_2 < acceptableDuration_3 < ...
A value_x with direction="high" shall be greater than a value_y with direction="low".
OperationalLimitValue
The limit set to which the limit values belong.
No
OperationalLimitSet
Values of equipment limits.
Yes
OperationalLimitType
The limit type associated with this limit.
Yes
OperationalLimit
The operational limits associated with this type of limit.
No
OperationalLimitDirectionKind
The direction attribute describes the side of a limit that is a violation.
high
High means that a monitored value above the limit value is a violation. If applied to a terminal flow, the positive direction is into the terminal.
low
Low means a monitored value below the limit is a violation. If applied to a terminal flow, the positive direction is into the terminal.
absoluteValue
An absoluteValue limit means that a monitored absolute value above the limit value is a violation.
OperationalLimitSet
A set of limits associated with equipment. Sets of limits might apply to a specific temperature, or season for example. A set of limits may contain different severities of limit levels that would apply to the same equipment. The set may contain limits of different types such as apparent power and current limits or high and low voltage limits that are logically applied together as a set.
OperationalLimitType
The operational meaning of a category of limits.
acceptableDuration
The nominal acceptable duration of the limit. Limits are commonly expressed in terms of the a time limit for which the limit is normally acceptable. The actual acceptable duration of a specific limit may depend on other local factors such as temperature or wind speed.
limitType
Entsoe
Types of limits defined in the ENTSO-E Operational Handbook Policy 3.
direction
The direction of the limit.
VoltageLimit
Operational limit applied to voltage.
value
Limit on voltage. High or low limit nature of the limit depends upon the properties of the operational limit type.
Wires
An extension to the Core and Topology package that models information on the electrical characteristics of Transmission and Distribution networks. This package is used by network applications such as State Estimation, Load Flow and Optimal Power Flow.
ACLineSegment
A wire or combination of wires, with consistent electrical characteristics, building a single electrical system, used to carry alternating current between points in the power system.
For symmetrical, transposed 3ph lines, it is sufficient to use attributes of the line segment, which describe impedances and admittances for the entire length of the segment. Additionally impedances can be computed by using length and associated per length impedances.
The BaseVoltage at the two ends of ACLineSegments in a Line shall have the same BaseVoltage.nominalVoltage. However, boundary lines may have slightly different BaseVoltage.nominalVoltages and variation is allowed. Larger voltage difference in general requires use of an equivalent branch.
b0ch
ShortCircuit
Zero sequence shunt (charging) susceptance, uniformly distributed, of the entire line section.
Susceptance
Imaginary part of admittance.
CIMDatatype
value
unit
multiplier
bch
Positive sequence shunt (charging) susceptance, uniformly distributed, of the entire line section. This value represents the full charging over the full length of the line.
g0ch
ShortCircuit
Zero sequence shunt (charging) conductance, uniformly distributed, of the entire line section.
Conductance
Factor by which voltage must be multiplied to give corresponding power lost from a circuit. Real part of admittance.
CIMDatatype
value
unit
multiplier
gch
Positive sequence shunt (charging) conductance, uniformly distributed, of the entire line section.
r
Positive sequence series resistance of the entire line section.
r0
ShortCircuit
Zero sequence series resistance of the entire line section.
shortCircuitEndTemperature
ShortCircuit
Maximum permitted temperature at the end of SC for the calculation of minimum short-circuit currents. Used for short circuit data exchange according to IEC 60909
Temperature
Value of temperature in degrees Celsius.
CIMDatatype
multiplier
unit
value
x
Positive sequence series reactance of the entire line section.
x0
ShortCircuit
Zero sequence series reactance of the entire line section.
AsynchronousMachine
A rotating machine whose shaft rotates asynchronously with the electrical field. Also known as an induction machine with no external connection to the rotor windings, e.g squirrel-cage induction machine.
converterFedDrive
ShortCircuit
Indicates whether the machine is a converter fed drive. Used for short circuit data exchange according to IEC 60909
efficiency
ShortCircuit
Efficiency of the asynchronous machine at nominal operation in percent. Indicator for converter drive motors. Used for short circuit data exchange according to IEC 60909
iaIrRatio
ShortCircuit
Ratio of locked-rotor current to the rated current of the motor (Ia/Ir). Used for short circuit data exchange according to IEC 60909
nominalFrequency
Nameplate data indicates if the machine is 50 or 60 Hz.
Frequency
Cycles per second.
CIMDatatype
value
unit
multiplier
nominalSpeed
Nameplate data. Depends on the slip and number of pole pairs.
RotationSpeed
Number of revolutions per second.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
polePairNumber
ShortCircuit
Number of pole pairs of stator. Used for short circuit data exchange according to IEC 60909
ratedMechanicalPower
ShortCircuit
Rated mechanical power (Pr in the IEC 60909-0). Used for short circuit data exchange according to IEC 60909.
reversible
ShortCircuit
Indicates for converter drive motors if the power can be reversible. Used for short circuit data exchange according to IEC 60909
rxLockedRotorRatio
ShortCircuit
Locked rotor ratio (R/X). Used for short circuit data exchange according to IEC 60909
Breaker
A mechanical switching device capable of making, carrying, and breaking currents under normal circuit conditions and also making, carrying for a specified time, and breaking currents under specified abnormal circuit conditions e.g. those of short circuit.
BusbarSection
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation.
Voltage measurements are typically obtained from VoltageTransformers that are connected to busbar sections. A bus bar section may have many physical terminals but for analysis is modelled with exactly one logical terminal.
ipMax
ShortCircuit
Maximum allowable peak short-circuit current of busbar (Ipmax in the IEC 60909-0).
Mechanical limit of the busbar in the substation itself. Used for short circuit data exchange according to IEC 60909
Conductor
Combination of conducting material with consistent electrical characteristics, building a single electrical system, used to carry current between points in the power system.
length
Segment length for calculating line section capabilities
Connector
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation and are modelled with a single logical terminal.
Disconnector
A manually operated or motor operated mechanical switching device used for changing the connections in a circuit, or for isolating a circuit or equipment from a source of power. It is required to open or close circuits when negligible current is broken or made.
EarthFaultCompensator
A conducting equipment used to represent a connection to ground which is typically used to compensate earth faults.. An earth fault compensator device modeled with a single terminal implies a second terminal solidly connected to ground. If two terminals are modeled, the ground is not assumed and normal connection rules apply.
ShortCircuit
r
Nominal resistance of device.
EnergyConsumer
Generic user of energy - a point of consumption on the power system model.
pfixed
Operation
Active power of the load that is a fixed quantity. Load sign convention is used, i.e. positive sign means flow out from a node.
pfixedPct
Operation
Fixed active power as per cent of load group fixed active power. Load sign convention is used, i.e. positive sign means flow out from a node.
qfixed
Operation
Reactive power of the load that is a fixed quantity. Load sign convention is used, i.e. positive sign means flow out from a node.
ReactivePower
Product of RMS value of the voltage and the RMS value of the quadrature component of the current.
CIMDatatype
value
unit
multiplier
qfixedPct
Operation
Fixed reactive power as per cent of load group fixed reactive power. Load sign convention is used, i.e. positive sign means flow out from a node.
LoadResponse
The load response characteristic of this load. If missing, this load is assumed to be constant power.
Yes
EnergyConsumer
The set of loads that have the response characteristics.
No
ExternalNetworkInjection
This class represents external network and it is used for IEC 60909 calculations.
governorSCD
Power Frequency Bias. This is the change in power injection divided by the change in frequency and negated. A positive value of the power frequency bias provides additional power injection upon a drop in frequency.
ActivePowerPerFrequency
Active power variation with frequency.
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
ikSecond
ShortCircuit
Indicates whether initial symmetrical short-circuit current and power have been calculated according to IEC (Ik").
maxInitialSymShCCurrent
ShortCircuit
Maximum initial symmetrical short-circuit currents (Ik" max) in A (Ik" = Sk"/(SQRT(3) Un)). Used for short circuit data exchange according to IEC 60909
maxP
Maximum active power of the injection.
maxQ
Not for short circuit modelling; It is used for modelling of infeed for load flow exchange. If maxQ and minQ are not used ReactiveCapabilityCurve can be used
maxR0ToX0Ratio
ShortCircuit
Maximum ratio of zero sequence resistance of Network Feeder to its zero sequence reactance (R(0)/X(0) max). Used for short circuit data exchange according to IEC 60909
maxR1ToX1Ratio
ShortCircuit
Maximum ratio of positive sequence resistance of Network Feeder to its positive sequence reactance (R(1)/X(1) max). Used for short circuit data exchange according to IEC 60909
maxZ0ToZ1Ratio
ShortCircuit
Maximum ratio of zero sequence impedance to its positive sequence impedance (Z(0)/Z(1) max). Used for short circuit data exchange according to IEC 60909
minInitialSymShCCurrent
ShortCircuit
Minimum initial symmetrical short-circuit currents (Ik" min) in A (Ik" = Sk"/(SQRT(3) Un)). Used for short circuit data exchange according to IEC 60909
minP
Minimum active power of the injection.
minQ
Not for short circuit modelling; It is used for modelling of infeed for load flow exchange. If maxQ and minQ are not used ReactiveCapabilityCurve can be used
minR0ToX0Ratio
ShortCircuit
Indicates whether initial symmetrical short-circuit current and power have been calculated according to IEC (Ik"). Used for short circuit data exchange according to IEC 6090
minR1ToX1Ratio
ShortCircuit
Minimum ratio of positive sequence resistance of Network Feeder to its positive sequence reactance (R(1)/X(1) min). Used for short circuit data exchange according to IEC 60909
minZ0ToZ1Ratio
ShortCircuit
Minimum ratio of zero sequence impedance to its positive sequence impedance (Z(0)/Z(1) min). Used for short circuit data exchange according to IEC 60909
voltageFactor
ShortCircuit
Voltage factor in pu, which was used to calculate short-circuit current Ik" and power Sk".
PU
Per Unit - a positive or negative value referred to a defined base. Values typically range from -10 to +10.
CIMDatatype
value
unit
multiplier
Ground
A point where the system is grounded used for connecting conducting equipment to ground. The power system model can have any number of grounds.
ShortCircuit
Operation
GroundDisconnector
A manually operated or motor operated mechanical switching device used for isolating a circuit or equipment from ground.
ShortCircuit
Operation
GroundingImpedance
A fixed impedance device used for grounding.
ShortCircuit
x
Reactance of device.
Junction
A point where one or more conducting equipments are connected with zero resistance.
Line
Contains equipment beyond a substation belonging to a power transmission line.
LinearShuntCompensator
A linear shunt compensator has banks or sections with equal admittance values.
b0PerSection
ShortCircuit
Zero sequence shunt (charging) susceptance per section
bPerSection
Positive sequence shunt (charging) susceptance per section
g0PerSection
ShortCircuit
Zero sequence shunt (charging) conductance per section
gPerSection
Positive sequence shunt (charging) conductance per section
LoadBreakSwitch
A mechanical switching device capable of making, carrying, and breaking currents under normal operating conditions.
MutualCoupling
This class represents the zero sequence line mutual coupling.
ShortCircuit
b0ch
Zero sequence mutual coupling shunt (charging) susceptance, uniformly distributed, of the entire line section.
distance11
Distance to the start of the coupled region from the first line's terminal having sequence number equal to 1.
distance12
Distance to the end of the coupled region from the first line's terminal with sequence number equal to 1.
distance21
Distance to the start of coupled region from the second line's terminal with sequence number equal to 1.
distance22
Distance to the end of coupled region from the second line's terminal with sequence number equal to 1.
g0ch
Zero sequence mutual coupling shunt (charging) conductance, uniformly distributed, of the entire line section.
r0
Zero sequence branch-to-branch mutual impedance coupling, resistance.
x0
Zero sequence branch-to-branch mutual impedance coupling, reactance.
NonlinearShuntCompensator
A non linear shunt compensator has bank or section admittance values that differs.
NonlinearShuntCompensator
Non-linear shunt compensator owning this point.
Yes
NonlinearShuntCompensatorPoints
All points of the non-linear shunt compensator.
No
NonlinearShuntCompensatorPoint
A non linear shunt compensator bank or section admittance value.
b
Positive sequence shunt (charging) susceptance per section
b0
ShortCircuit
Zero sequence shunt (charging) susceptance per section
g
Positive sequence shunt (charging) conductance per section
g0
ShortCircuit
Zero sequence shunt (charging) conductance per section
sectionNumber
The number of the section.
PetersenCoil
A tunable impedance device normally used to offset line charging during single line faults in an ungrounded section of network.
ShortCircuit
mode
The mode of operation of the Petersen coil.
PetersenCoilModeKind
The mode of operation for a Petersen coil.
fixed
Fixed position.
manual
Manual positioning.
automaticPositioning
Automatic positioning.
nominalU
The nominal voltage for which the coil is designed.
offsetCurrent
The offset current that the Petersen coil controller is operating from the resonant point. This is normally a fixed amount for which the controller is configured and could be positive or negative. Typically 0 to 60 Amperes depending on voltage and resonance conditions.
positionCurrent
The control current used to control the Petersen coil also known as the position current. Typically in the range of 20-200mA.
xGroundMax
The maximum reactance.
xGroundMin
The minimum reactance.
xGroundNominal
The nominal reactance. This is the operating point (normally over compensation) that is defined based on the resonance point in the healthy network condition. The impedance is calculated based on nominal voltage divided by position current.
PhaseTapChanger
A transformer phase shifting tap model that controls the phase angle difference across the power transformer and potentially the active power flow through the power transformer. This phase tap model may also impact the voltage magnitude.
TransformerEnd
Phase tap changer associated with this transformer end.
Yes
PhaseTapChanger
Transformer end to which this phase tap changer belongs.
No
PhaseTapChangerAsymmetrical
Describes the tap model for an asymmetrical phase shifting transformer in which the difference voltage vector adds to the primary side voltage. The angle between the primary side voltage and the difference voltage is named the winding connection angle. The phase shift depends on both the difference voltage magnitude and the winding connection angle.
windingConnectionAngle
The phase angle between the in-phase winding and the out-of -phase winding used for creating phase shift. The out-of-phase winding produces what is known as the difference voltage. Setting this angle to 90 degrees is not the same as a symmemtrical transformer.
PhaseTapChangerLinear
Describes a tap changer with a linear relation between the tap step and the phase angle difference across the transformer. This is a mathematical model that is an approximation of a real phase tap changer.
The phase angle is computed as stepPhaseShitfIncrement times the tap position.
The secondary side voltage magnitude is the same as at the primary side.
stepPhaseShiftIncrement
Phase shift per step position. A positive value indicates a positive phase shift from the winding where the tap is located to the other winding (for a two-winding transformer).
The actual phase shift increment might be more accurately computed from the symmetrical or asymmetrical models or a tap step table lookup if those are available.
xMax
The reactance depend on the tap position according to a "u" shaped curve. The maximum reactance (xMax) appear at the low and high tap positions.
xMin
The reactance depend on the tap position according to a "u" shaped curve. The minimum reactance (xMin) appear at the mid tap position.
PhaseTapChangerNonLinear
The non-linear phase tap changer describes the non-linear behavior of a phase tap changer. This is a base class for the symmetrical and asymmetrical phase tap changer models. The details of these models can be found in the IEC 61970-301 document.
voltageStepIncrement
The voltage step increment on the out of phase winding specified in percent of nominal voltage of the transformer end.
xMax
The reactance depend on the tap position according to a "u" shaped curve. The maximum reactance (xMax) appear at the low and high tap positions.
xMin
The reactance depend on the tap position according to a "u" shaped curve. The minimum reactance (xMin) appear at the mid tap position.
PhaseTapChangerSymmetrical
Describes a symmetrical phase shifting transformer tap model in which the secondary side voltage magnitude is the same as at the primary side. The difference voltage magnitude is the base in an equal-sided triangle where the sides corresponds to the primary and secondary voltages. The phase angle difference corresponds to the top angle and can be expressed as twice the arctangent of half the total difference voltage.
PhaseTapChangerTable
Describes a tabular curve for how the phase angle difference and impedance varies with the tap step.
PhaseTapChangerTable
The table of this point.
Yes
PhaseTapChangerTablePoint
The points of this table.
No
PhaseTapChangerTabular
The phase tap changers to which this phase tap table applies.
No
PhaseTapChangerTable
The phase tap changer table for this phase tap changer.
Yes
PhaseTapChangerTablePoint
Describes each tap step in the phase tap changer tabular curve.
angle
The angle difference in degrees.
PhaseTapChangerTabular
PowerTransformer
An electrical device consisting of two or more coupled windings, with or without a magnetic core, for introducing mutual coupling between electric circuits. Transformers can be used to control voltage and phase shift (active power flow).
A power transformer may be composed of separate transformer tanks that need not be identical.
A power transformer can be modeled with or without tanks and is intended for use in both balanced and unbalanced representations. A power transformer typically has two terminals, but may have one (grounding), three or more terminals.
The inherited association ConductingEquipment.BaseVoltage should not be used. The association from TransformerEnd to BaseVoltage should be used instead.
beforeShCircuitHighestOperatingCurrent
ShortCircuit
The highest operating current (Ib in the IEC 60909-0) before short circuit (depends on network configuration and relevant reliability philosophy). It is used for calculation of the impedance correction factor KT defined in IEC 60909-0.
beforeShCircuitHighestOperatingVoltage
ShortCircuit
The highest operating voltage (Ub in the IEC 60909-0) before short circuit. It is used for calculation of the impedance correction factor KT defined in IEC 60909-0. This is worst case voltage on the low side winding (Section 3.7.1 in the standard). Used to define operating conditions.
beforeShortCircuitAnglePf
ShortCircuit
The angle of power factor before short circuit (phib in the IEC 60909-0). It is used for calculation of the impedance correction factor KT defined in IEC 60909-0. This is the worst case power factor. Used to define operating conditions.
highSideMinOperatingU
ShortCircuit
The minimum operating voltage (uQmin in the IEC 60909-0) at the high voltage side (Q side) of the unit transformer of the power station unit. A value well established from long-term operating experience of the system. It is used for calculation of the impedance correction factor KG defined in IEC 60909-0
isPartOfGeneratorUnit
ShortCircuit
Indicates whether the machine is part of a power station unit. Used for short circuit data exchange according to IEC 60909
operationalValuesConsidered
ShortCircuit
It is used to define if the data (other attributes related to short circuit data exchange) defines long term operational conditions or not. Used for short circuit data exchange according to IEC 60909.
PowerTransformer
The ends of this power transformer.
Yes
PowerTransformerEnd
The power transformer of this power transformer end.
No
PowerTransformerEnd
A PowerTransformerEnd is associated with each Terminal of a PowerTransformer.
The impedance values r, r0, x, and x0 of a PowerTransformerEnd represents a star equivalent as follows
1) for a two Terminal PowerTransformer the high voltage PowerTransformerEnd has non zero values on r, r0, x, and x0 while the low voltage PowerTransformerEnd has zero values for r, r0, x, and x0.
2) for a three Terminal PowerTransformer the three PowerTransformerEnds represents a star equivalent with each leg in the star represented by r, r0, x, and x0 values.
3) for a PowerTransformer with more than three Terminals the PowerTransformerEnd impedance values cannot be used. Instead use the TransformerMeshImpedance or split the transformer into multiple PowerTransformers.
b
Magnetizing branch susceptance (B mag). The value can be positive or negative.
connectionKind
Kind of connection.
WindingConnection
Winding connection type.
D
Delta
Y
Wye
Z
ZigZag
Yn
Wye, with neutral brought out for grounding.
Zn
ZigZag, with neutral brought out for grounding.
A
Autotransformer common winding
I
Independent winding, for single-phase connections
b0
ShortCircuit
Zero sequence magnetizing branch susceptance.
phaseAngleClock
ShortCircuit
Terminal voltage phase angle displacement where 360 degrees are represented with clock hours. The valid values are 0 to 11. For example, for the secondary side end of a transformer with vector group code of 'Dyn11', specify the connection kind as wye with neutral and specify the phase angle of the clock as 11. The clock value of the transformer end number specified as 1, is assumed to be zero. Note the transformer end number is not assumed to be the same as the terminal sequence number.
ratedS
Normal apparent power rating.
The attribute shall be a positive value. For a two-winding transformer the values for the high and low voltage sides shall be identical.
g
Magnetizing branch conductance.
ratedU
Rated voltage: phase-phase for three-phase windings, and either phase-phase or phase-neutral for single-phase windings.
A high voltage side, as given by TransformerEnd.endNumber, shall have a ratedU that is greater or equal than ratedU for the lower voltage sides.
g0
ShortCircuit
Zero sequence magnetizing branch conductance (star-model).
r
Resistance (star-model) of the transformer end.
The attribute shall be equal or greater than zero for non-equivalent transformers.
r0
ShortCircuit
Zero sequence series resistance (star-model) of the transformer end.
x
Positive sequence series reactance (star-model) of the transformer end.
x0
ShortCircuit
Zero sequence series reactance of the transformer end.
ProtectedSwitch
A ProtectedSwitch is a switching device that can be operated by ProtectionEquipment.
RatioTapChanger
A tap changer that changes the voltage ratio impacting the voltage magnitude but not the phase angle across the transformer.
tculControlMode
Specifies the regulation control mode (voltage or reactive) of the RatioTapChanger.
TransformerControlMode
Control modes for a transformer.
volt
Voltage control
reactive
Reactive power flow control
stepVoltageIncrement
Tap step increment, in per cent of nominal voltage, per step position.
RatioTapChanger
The tap ratio table for this ratio tap changer.
No
RatioTapChangerTable
The ratio tap changer of this tap ratio table.
Yes
TransformerEnd
Ratio tap changer associated with this transformer end.
Yes
RatioTapChanger
Transformer end to which this ratio tap changer belongs.
No
RatioTapChangerTable
Describes a curve for how the voltage magnitude and impedance varies with the tap step.
RatioTapChangerTablePoint
Table of this point.
No
RatioTapChangerTable
Points of this table.
Yes
RatioTapChangerTablePoint
Describes each tap step in the ratio tap changer tabular curve.
ReactiveCapabilityCurve
Reactive power rating envelope versus the synchronous machine's active power, in both the generating and motoring modes. For each active power value there is a corresponding high and low reactive power limit value. Typically there will be a separate curve for each coolant condition, such as hydrogen pressure. The Y1 axis values represent reactive minimum and the Y2 axis values represent reactive maximum.
ReactiveCapabilityCurve
The equivalent injection using this reactive capability curve.
Yes
EquivalentInjection
The reactive capability curve used by this equivalent injection.
No
InitialReactiveCapabilityCurve
Synchronous machines using this curve as default.
Yes
InitiallyUsedBySynchronousMachines
The default reactive capability curve for use by a synchronous machine.
No
RegulatingCondEq
A type of conducting equipment that can regulate a quantity (i.e. voltage or flow) at a specific point in the network.
RegulatingControl
The regulating control scheme in which this equipment participates.
Yes
RegulatingCondEq
The equipment that participates in this regulating control scheme.
No
RegulatingControl
Specifies a set of equipment that works together to control a power system quantity such as voltage or flow.
Remote bus voltage control is possible by specifying the controlled terminal located at some place remote from the controlling equipment.
In case multiple equipment, possibly of different types, control same terminal there must be only one RegulatingControl at that terminal. The most specific subtype of RegulatingControl shall be used in case such equipment participate in the control, e.g. TapChangerControl for tap changers.
For flow control load sign convention is used, i.e. positive sign means flow out from a TopologicalNode (bus) into the conducting equipment.
mode
The regulating control mode presently available. This specification allows for determining the kind of regulation without need for obtaining the units from a schedule.
RegulatingControlModeKind
The kind of regulation model. For example regulating voltage, reactive power, active power, etc.
voltage
Voltage is specified.
activePower
Active power is specified.
reactivePower
Reactive power is specified.
currentFlow
Current flow is specified.
admittance
Admittance is specified.
timeScheduled
Control switches on/off by time of day. The times may change on the weekend, or in different seasons.
temperature
Control switches on/off based on the local temperature (i.e., a thermostat).
powerFactor
Power factor is specified.
RegulatingControl
Regulating controls that have this Schedule.
Yes
RegulationSchedule
Schedule for this Regulating regulating control.
No
RegulationSchedule
A pre-established pattern over time for a controlled variable, e.g., busbar voltage.
Operation
RotatingMachine
A rotating machine which may be used as a generator or motor.
ratedPowerFactor
Power factor (nameplate data). It is primarily used for short circuit data exchange according to IEC 60909.
ratedS
Nameplate apparent power rating for the unit.
The attribute shall have a positive value.
ratedU
Rated voltage (nameplate data, Ur in IEC 60909-0). It is primarily used for short circuit data exchange according to IEC 60909.
SeriesCompensator
A Series Compensator is a series capacitor or reactor or an AC transmission line without charging susceptance. It is a two terminal device.
r
Positive sequence resistance.
r0
ShortCircuit
Zero sequence resistance.
x
Positive sequence reactance.
x0
ShortCircuit
Zero sequence reactance.
varistorPresent
Describe if a metal oxide varistor (mov) for over voltage protection is configured at the series compensator.
varistorRatedCurrent
The maximum current the varistor is designed to handle at specified duration.
varistorVoltageThreshold
The dc voltage at which the varistor start conducting.
ShortCircuitRotorKind
Type of rotor, used by short circuit applications.
salientPole1
Salient pole 1 in the IEC 60909
salientPole2
Salient pole 2 in IEC 60909
turboSeries1
Turbo Series 1 in the IEC 60909
turboSeries2
Turbo series 2 in IEC 60909
ShuntCompensator
A shunt capacitor or reactor or switchable bank of shunt capacitors or reactors. A section of a shunt compensator is an individual capacitor or reactor. A negative value for reactivePerSection indicates that the compensator is a reactor. ShuntCompensator is a single terminal device. Ground is implied.
aVRDelay
Time delay required for the device to be connected or disconnected by automatic voltage regulation (AVR).
grounded
Used for Yn and Zn connections. True if the neutral is solidly grounded.
maximumSections
The maximum number of sections that may be switched in.
nomU
The voltage at which the nominal reactive power may be calculated. This should normally be within 10% of the voltage at which the capacitor is connected to the network.
normalSections
The normal number of sections switched in.
switchOnCount
The switch on count since the capacitor count was last reset or initialized.
switchOnDate
The date and time when the capacitor bank was last switched on.
voltageSensitivity
Voltage sensitivity required for the device to regulate the bus voltage, in voltage/reactive power.
VoltagePerReactivePower
Voltage variation with reactive power.
CIMDatatype
value
unit
denominatorMultiplier
multiplier
denominatorUnit
StaticVarCompensator
A facility for providing variable and controllable shunt reactive power. The SVC typically consists of a stepdown transformer, filter, thyristor-controlled reactor, and thyristor-switched capacitor arms.
The SVC may operate in fixed MVar output mode or in voltage control mode. When in voltage control mode, the output of the SVC will be proportional to the deviation of voltage at the controlled bus from the voltage setpoint. The SVC characteristic slope defines the proportion. If the voltage at the controlled bus is equal to the voltage setpoint, the SVC MVar output is zero.
capacitiveRating
Maximum available capacitive reactance.
inductiveRating
Maximum available inductive reactance.
slope
The characteristics slope of an SVC defines how the reactive power output changes in proportion to the difference between the regulated bus voltage and the voltage setpoint.
sVCControlMode
SVC control mode.
SVCControlMode
Static VAr Compensator control mode.
reactivePower
voltage
voltageSetPoint
The reactive power output of the SVC is proportional to the difference between the voltage at the regulated bus and the voltage setpoint. When the regulated bus voltage is equal to the voltage setpoint, the reactive power output is zero.
Switch
A generic device designed to close, or open, or both, one or more electric circuits. All switches are two terminal devices including grounding switches.
normalOpen
The attribute is used in cases when no Measurement for the status value is present. If the Switch has a status measurement the Discrete.normalValue is expected to match with the Switch.normalOpen.
ratedCurrent
The maximum continuous current carrying capacity in amps governed by the device material and construction.
retained
Branch is retained in a bus branch model. The flow through retained switches will normally be calculated in power flow.
Switch
A Switch can be associated with SwitchSchedules.
Yes
SwitchSchedules
A SwitchSchedule is associated with a Switch.
No
SwitchSchedule
A schedule of switch positions. If RegularTimePoint.value1 is 0, the switch is open. If 1, the switch is closed.
Operation
SynchronousMachine
An electromechanical device that operates with shaft rotating synchronously with the network. It is a single machine operating either as a generator or synchronous condenser or pump.
earthing
ShortCircuit
Indicates whether or not the generator is earthed. Used for short circuit data exchange according to IEC 60909
earthingStarPointR
ShortCircuit
Generator star point earthing resistance (Re). Used for short circuit data exchange according to IEC 60909
earthingStarPointX
ShortCircuit
Generator star point earthing reactance (Xe). Used for short circuit data exchange according to IEC 60909
ikk
ShortCircuit
Steady-state short-circuit current (in A for the profile) of generator with compound excitation during 3-phase short circuit.
- Ikk=0: Generator with no compound excitation.
- Ikk?0: Generator with compound excitation.
Ikk is used to calculate the minimum steady-state short-circuit current for generators with compound excitation
(Section 4.6.1.2 in the IEC 60909-0)
Used only for single fed short circuit on a generator. (Section 4.3.4.2. in the IEC 60909-0)
maxQ
Maximum reactive power limit. This is the maximum (nameplate) limit for the unit.
minQ
Minimum reactive power limit for the unit.
mu
ShortCircuit
Factor to calculate the breaking current (Section 4.5.2.1 in the IEC 60909-0).
Used only for single fed short circuit on a generator (Section 4.3.4.2. in the IEC 60909-0).
qPercent
Percent of the coordinated reactive control that comes from this machine.
r0
ShortCircuit
Zero sequence resistance of the synchronous machine.
r2
ShortCircuit
Negative sequence resistance.
satDirectSubtransX
ShortCircuit
Direct-axis subtransient reactance saturated, also known as Xd"sat.
satDirectSyncX
ShortCircuit
Direct-axes saturated synchronous reactance (xdsat); reciprocal of short-circuit ration. Used for short circuit data exchange, only for single fed short circuit on a generator. (Section 4.3.4.2. in the IEC 60909-0).
satDirectTransX
ShortCircuit
Saturated Direct-axis transient reactance. The attribute is primarily used for short circuit calculations according to ANSI.
shortCircuitRotorType
ShortCircuit
Type of rotor, used by short circuit applications, only for single fed short circuit according to IEC 60909.
type
Modes that this synchronous machine can operate in.
SynchronousMachineKind
Synchronous machine type.
generator
condenser
generatorOrCondenser
motor
generatorOrMotor
motorOrCondenser
generatorOrCondenserOrMotor
voltageRegulationRange
ShortCircuit
Range of generator voltage regulation (PG in the IEC 60909-0) used for calculation of the impedance correction factor KG defined in IEC 60909-0
This attribute is used to describe the operating voltage of the generating unit.
r
ShortCircuit
Equivalent resistance (RG) of generator. RG is considered for the calculation of all currents, except for the calculation of the peak current ip. Used for short circuit data exchange according to IEC 60909
x0
ShortCircuit
Zero sequence reactance of the synchronous machine.
x2
ShortCircuit
Negative sequence reactance.
TapChanger
Mechanism for changing transformer winding tap positions.
highStep
Highest possible tap step position, advance from neutral.
The attribute shall be greater than lowStep.
lowStep
Lowest possible tap step position, retard from neutral
ltcFlag
Specifies whether or not a TapChanger has load tap changing capabilities.
neutralStep
The neutral tap step position for this winding.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
neutralU
Voltage at which the winding operates at the neutral tap setting.
normalStep
The tap step position used in "normal" network operation for this winding. For a "Fixed" tap changer indicates the current physical tap setting.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
TapChanger
The regulating control scheme in which this tap changer participates.
No
TapChangerControl
The tap changers that participates in this regulating tap control scheme.
Yes
TapSchedules
A TapSchedule is associated with a TapChanger.
No
TapChanger
A TapChanger can have TapSchedules.
Yes
TapChangerControl
Describes behavior specific to tap changers, e.g. how the voltage at the end of a line varies with the load level and compensation of the voltage drop by tap adjustment.
TapChangerTablePoint
b
The magnetizing branch susceptance deviation in percent of nominal value. The actual susceptance is calculated as follows:
calculated magnetizing susceptance = b(nominal) * (1 + b(from this class)/100). The b(nominal) is defined as the static magnetizing susceptance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
g
The magnetizing branch conductance deviation in percent of nominal value. The actual conductance is calculated as follows:
calculated magnetizing conductance = g(nominal) * (1 + g(from this class)/100). The g(nominal) is defined as the static magnetizing conductance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
r
The resistance deviation in percent of nominal value. The actual reactance is calculated as follows:
calculated resistance = r(nominal) * (1 + r(from this class)/100). The r(nominal) is defined as the static resistance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
ratio
The voltage ratio in per unit. Hence this is a value close to one.
step
The tap step.
x
The series reactance deviation in percent of nominal value. The actual reactance is calculated as follows:
calculated reactance = x(nominal) * (1 + x(from this class)/100). The x(nominal) is defined as the static series reactance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
TapSchedule
A pre-established pattern over time for a tap step.
Operation
TransformerEnd
A conducting connection point of a power transformer. It corresponds to a physical transformer winding terminal. In earlier CIM versions, the TransformerWinding class served a similar purpose, but this class is more flexible because it associates to terminal but is not a specialization of ConductingEquipment.
rground
ShortCircuit
(for Yn and Zn connections) Resistance part of neutral impedance where 'grounded' is true.
endNumber
Number for this transformer end, corresponding to the end's order in the power transformer vector group or phase angle clock number. Highest voltage winding should be 1. Each end within a power transformer should have a unique subsequent end number. Note the transformer end number need not match the terminal sequence number.
grounded
ShortCircuit
(for Yn and Zn connections) True if the neutral is solidly grounded.
xground
ShortCircuit
(for Yn and Zn connections) Reactive part of neutral impedance where 'grounded' is true.
LoadModel
This package is responsible for modeling the energy consumers and the system load as curves and associated curve data. Special circumstances that may affect the load, such as seasons and daytypes, are also included here.
This information is used by Load Forecasting and Load Management.
ConformLoad
ConformLoad represent loads that follow a daily load change pattern where the pattern can be used to scale the load with a system load.
EnergyConsumers
Conform loads assigned to this ConformLoadGroup.
No
LoadGroup
Group of this ConformLoad.
Yes
ConformLoadGroup
A group of loads conforming to an allocation pattern.
ConformLoadSchedules
The ConformLoadSchedules in the ConformLoadGroup.
No
ConformLoadGroup
The ConformLoadGroup where the ConformLoadSchedule belongs.
Yes
ConformLoadSchedule
A curve of load versus time (X-axis) showing the active power values (Y1-axis) and reactive power (Y2-axis) for each unit of the period covered. This curve represents a typical pattern of load over the time period for a given day type and season.
DayType
Group of similar days. For example it could be used to represent weekdays, weekend, or holidays.
Operation
DayType
Schedules that use this DayType.
Yes
SeasonDayTypeSchedules
DayType for the Schedule.
No
EnergyArea
Describes an area having energy production or consumption. Specializations are intended to support the load allocation function as typically required in energy management systems or planning studies to allocate hypothesized load levels to individual load points for power flow analysis. Often the energy area can be linked to both measured and forecast load levels.
Operation
EnergyArea
The energy area that is forecast from this control area specification.
Yes
Operation
ControlArea
The control area specification that is used for the load forecast.
No
Operation
LoadArea
The class is the root or first level in a hierarchical structure for grouping of loads for the purpose of load flow load scaling.
Operation
SubLoadAreas
The SubLoadAreas in the LoadArea.
No
LoadArea
The LoadArea where the SubLoadArea belongs.
Yes
LoadGroup
The class is the third level in a hierarchical structure for grouping of loads for the purpose of load flow load scaling.
LoadGroups
The Loadgroups in the SubLoadArea.
No
SubLoadArea
The SubLoadArea where the Loadgroup belongs.
Yes
LoadResponseCharacteristic
Models the characteristic response of the load demand due to changes in system conditions such as voltage and frequency. This is not related to demand response.
If LoadResponseCharacteristic.exponentModel is True, the voltage exponents are specified and used as to calculate:
Active power component = Pnominal * (Voltage/cim:BaseVoltage.nominalVoltage) ** cim:LoadResponseCharacteristic.pVoltageExponent
Reactive power component = Qnominal * (Voltage/cim:BaseVoltage.nominalVoltage)** cim:LoadResponseCharacteristic.qVoltageExponent
Where * means "multiply" and ** is "raised to power of".
exponentModel
Indicates the exponential voltage dependency model is to be used. If false, the coefficient model is to be used.
The exponential voltage dependency model consist of the attributes
- pVoltageExponent
- qVoltageExponent.
The coefficient model consist of the attributes
- pConstantImpedance
- pConstantCurrent
- pConstantPower
- qConstantImpedance
- qConstantCurrent
- qConstantPower.
The sum of pConstantImpedance, pConstantCurrent and pConstantPower shall equal 1.
The sum of qConstantImpedance, qConstantCurrent and qConstantPower shall equal 1.
pConstantCurrent
Portion of active power load modeled as constant current.
pConstantImpedance
Portion of active power load modeled as constant impedance.
pConstantPower
Portion of active power load modeled as constant power.
pFrequencyExponent
Exponent of per unit frequency effecting active power.
pVoltageExponent
Exponent of per unit voltage effecting real power.
qConstantCurrent
Portion of reactive power load modeled as constant current.
qConstantImpedance
Portion of reactive power load modeled as constant impedance.
qConstantPower
Portion of reactive power load modeled as constant power.
qFrequencyExponent
Exponent of per unit frequency effecting reactive power.
qVoltageExponent
Exponent of per unit voltage effecting reactive power.
NonConformLoad
NonConformLoad represent loads that do not follow a daily load change pattern and changes are not correlated with the daily load change pattern.
LoadGroup
Conform loads assigned to this ConformLoadGroup.
Yes
EnergyConsumers
Group of this ConformLoad.
No
NonConformLoadGroup
Loads that do not follow a daily and seasonal load variation pattern.
NonConformLoadSchedules
The NonConformLoadSchedules in the NonConformLoadGroup.
No
NonConformLoadGroup
The NonConformLoadGroup where the NonConformLoadSchedule belongs.
Yes
NonConformLoadSchedule
An active power (Y1-axis) and reactive power (Y2-axis) schedule (curves) versus time (X-axis) for non-conforming loads, e.g., large industrial load or power station service (where modeled).
Season
A specified time period of the year.
Operation
endDate
Date season ends.
MonthDay
MonthDay format as "--mm-dd", which conforms with XSD data type gMonthDay.
Primitive
startDate
Date season starts.
Season
Schedules that use this Season.
Yes
SeasonDayTypeSchedules
Season for the Schedule.
No
SeasonDayTypeSchedule
A time schedule covering a 24 hour period, with curve data for a specific type of season and day.
Operation
StationSupply
Station supply with load derived from the station output.
Operation
SubLoadArea
The class is the second level in a hierarchical structure for grouping of loads for the purpose of load flow load scaling.
Operation
Equivalents
The equivalents package models equivalent networks.
EquivalentBranch
The class represents equivalent branches.
negativeR12
ShortCircuit
Negative sequence series resistance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
EquivalentBranch is a result of network reduction prior to the data exchange
negativeR21
ShortCircuit
Negative sequence series resistance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
EquivalentBranch is a result of network reduction prior to the data exchange
negativeX12
ShortCircuit
Negative sequence series reactance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
negativeX21
ShortCircuit
Negative sequence series reactance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909.
Usage: EquivalentBranch is a result of network reduction prior to the data exchange
positiveR12
ShortCircuit
Positive sequence series resistance from terminal sequence 1 to terminal sequence 2 . Used for short circuit data exchange according to IEC 60909.
EquivalentBranch is a result of network reduction prior to the data exchange.
positiveR21
ShortCircuit
Positive sequence series resistance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
EquivalentBranch is a result of network reduction prior to the data exchange
positiveX12
ShortCircuit
Positive sequence series reactance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
positiveX21
ShortCircuit
Positive sequence series reactance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
r
Positive sequence series resistance of the reduced branch.
r21
Resistance from terminal sequence 2 to terminal sequence 1 .Used for steady state power flow. This attribute is optional and represent unbalanced network such as off-nominal phase shifter. If only EquivalentBranch.r is given, then EquivalentBranch.r21 is assumed equal to EquivalentBranch.r.
Usage rule : EquivalentBranch is a result of network reduction prior to the data exchange.
x
Positive sequence series reactance of the reduced branch.
x21
Reactance from terminal sequence 2 to terminal sequence 1 .Used for steady state power flow. This attribute is optional and represent unbalanced network such as off-nominal phase shifter. If only EquivalentBranch.x is given, then EquivalentBranch.x21 is assumed equal to EquivalentBranch.x.
Usage rule : EquivalentBranch is a result of network reduction prior to the data exchange.
zeroR12
ShortCircuit
Zero sequence series resistance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
EquivalentBranch is a result of network reduction prior to the data exchange
zeroR21
ShortCircuit
Zero sequence series resistance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
zeroX12
ShortCircuit
Zero sequence series reactance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
zeroX21
ShortCircuit
Zero sequence series reactance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
EquivalentEquipment
The class represents equivalent objects that are the result of a network reduction. The class is the base for equivalent objects of different types.
EquivalentEquipments
The equivalent where the reduced model belongs.
No
EquivalentNetwork
The associated reduced equivalents.
Yes
EquivalentInjection
This class represents equivalent injections (generation or load). Voltage regulation is allowed only at the point of connection.
maxP
Maximum active power of the injection.
maxQ
Used for modeling of infeed for load flow exchange. Not used for short circuit modeling. If maxQ and minQ are not used ReactiveCapabilityCurve can be used.
minP
Minimum active power of the injection.
minQ
Used for modeling of infeed for load flow exchange. Not used for short circuit modeling. If maxQ and minQ are not used ReactiveCapabilityCurve can be used.
r
ShortCircuit
Positive sequence resistance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
r0
ShortCircuit
Zero sequence resistance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
r2
ShortCircuit
Negative sequence resistance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
regulationCapability
Specifies whether or not the EquivalentInjection has the capability to regulate the local voltage.
x
ShortCircuit
Positive sequence reactance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
x0
ShortCircuit
Zero sequence reactance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
x2
ShortCircuit
Negative sequence reactance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
EquivalentNetwork
A class that represents an external meshed network that has been reduced to an electrically equivalent model. The ConnectivityNodes contained in the equivalent are intended to reflect internal nodes of the equivalent. The boundary Connectivity nodes where the equivalent connects outside itself are NOT contained by the equivalent.
EquivalentShunt
The class represents equivalent shunts.
b
Positive sequence shunt susceptance.
g
Positive sequence shunt conductance.
ControlArea
The ControlArea package models area specifications which can be used for a variety of purposes. The package as a whole models potentially overlapping control area specifications for the purpose of actual generation control, load forecast area load capture, or powerflow based analysis.
ControlArea
A control area is a grouping of generating units and/or loads and a cutset of tie lines (as terminals) which may be used for a variety of purposes including automatic generation control, powerflow solution area interchange control specification, and input to load forecasting. Note that any number of overlapping control area specifications can be superimposed on the physical model.
type
The primary type of control area definition used to determine if this is used for automatic generation control, for planning interchange control, or other purposes. A control area specified with primary type of automatic generation control could still be forecast and used as an interchange area in power flow analysis.
ControlAreaTypeKind
The type of control area.
AGC
Used for automatic generation control.
Forecast
Used for load forecast.
Interchange
Used for interchange specification or control.
ControlArea
The control area of the tie flows.
Yes
TieFlow
The tie flows associated with the control area.
No
ControlArea
The parent control area for the generating unit specifications.
Yes
ControlAreaGeneratingUnit
The generating unit specificaitons for the control area.
No
ControlAreaGeneratingUnit
A control area generating unit. This class is needed so that alternate control area definitions may include the same generating unit. Note only one instance within a control area should reference a specific generating unit.
TieFlow
A flow specification in terms of location and direction for a control area.
positiveFlowIn
True if the flow into the terminal (load convention) is also flow into the control area. For example, this attribute should be true if using the tie line terminal further away from the control area. For example to represent a tie to a shunt component (like a load or generator) in another area, this is the near end of a branch and this attribute would be specified as false.
PK ! r! ! ^ cimpyorm/res/schemata/CIM16/EquipmentProfileCoreShortCircuitRDFSAugmented-v2_4_15-4Jul2016.rdf
EquipmentProfile
This profile has been built on the basis of the IEC 61970-452 document and adjusted to fit the purpose of the ENTSO-E CGMES.
EquipmentVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURIcore
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
baseURIoperation
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
baseURIshortCircuit
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURIcore
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentCore/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIoperation
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentOperation/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
entsoeURIshortCircuit
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/EquipmentShortCircuit/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
DC
ACDCConverter
A unit with valves for three phases, together with unit control equipment, essential protective and switching devices, DC storage capacitors, phase reactors and auxiliaries, if any, used for conversion.
baseS
Base apparent power of the converter pole.
ApparentPower
Product of the RMS value of the voltage and the RMS value of the current.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
idleLoss
Active power loss in pole at no power transfer. Converter configuration data used in power flow.
ActivePower
Product of RMS value of the voltage and the RMS value of the in-phase component of the current.
CIMDatatype
value
unit
multiplier
maxUdc
The maximum voltage on the DC side at which the converter should operate. Converter configuration data used in power flow.
Voltage
Electrical voltage, can be both AC and DC.
CIMDatatype
value
unit
multiplier
minUdc
Min allowed converter DC voltage. Converter configuration data used in power flow.
numberOfValves
Number of valves in the converter. Used in loss calculations.
Integer
An integer number. The range is unspecified and not limited.
Primitive
ratedUdc
Rated converter DC voltage, also called UdN. Converter configuration data used in power flow.
resistiveLoss
Converter configuration data used in power flow. Refer to poleLossP.
Resistance
Resistance (real part of impedance).
CIMDatatype
value
unit
multiplier
switchingLoss
Switching losses, relative to the base apparent power 'baseS'.
Refer to poleLossP.
ActivePowerPerCurrentFlow
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
valveU0
Valve threshold voltage. Forward voltage drop when the valve is conducting. Used in loss calculations, i.e. the switchLoss depend on numberOfValves * valveU0.
ACDCConverterDCTerminal
A DC electrical connection point at the AC/DC converter. The AC/DC converter is electrically connected also to the AC side. The AC connection is inherited from the AC conducting equipment in the same way as any other AC equipment. The AC/DC converter DC terminal is separate from generic DC terminal to restrict the connection with the AC side to AC/DC converter and so that no other DC conducting equipment can be connected to the AC side.
polarity
Represents the normal network polarity condition.
DCPolarityKind
Polarity for DC circuits.
positive
Positive pole.
middle
Middle pole, potentially grounded.
negative
Negative pole.
CsConverter
DC side of the current source converter (CSC).
maxAlpha
Maximum firing angle. CSC configuration data used in power flow.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
multiplier
maxGamma
Maximum extinction angle. CSC configuration data used in power flow.
maxIdc
The maximum direct current (Id) on the DC side at which the converter should operate. Converter configuration data use in power flow.
CurrentFlow
Electrical current with sign convention: positive flow is out of the conducting equipment into the connectivity node. Can be both AC and DC.
CIMDatatype
value
unit
multiplier
minAlpha
Minimum firing angle. CSC configuration data used in power flow.
minGamma
Minimum extinction angle. CSC configuration data used in power flow.
minIdc
The minimum direct current (Id) on the DC side at which the converter should operate. CSC configuration data used in power flow.
ratedIdc
Rated converter DC current, also called IdN. Converter configuration data used in power flow.
DCBaseTerminal
An electrical connection point at a piece of DC conducting equipment. DC terminals are connected at one physical DC node that may have multiple DC terminals connected. A DC node is similar to an AC connectivity node. The model enforces that DC connections are distinct from AC connections.
DCBreaker
A breaker within a DC system.
DCBusbar
A busbar within a DC system.
DCChopper
Low resistance equipment used in the internal DC circuit to balance voltages. It has typically positive and negative pole terminals and a ground.
DCConductingEquipment
The parts of the DC power system that are designed to carry current or that are conductively connected through DC terminals.
DCConverterOperatingModeKind
The operating mode of an HVDC bipole.
bipolar
Bipolar operation.
monopolarMetallicReturn
Monopolar operation with metallic return
monopolarGroundReturn
Monopolar operation with ground return
DCConverterUnit
Indivisible operative unit comprising all equipment between the point of common coupling on the AC side and the point of common coupling – DC side, essentially one or more converters, together with one or more converter transformers, converter control equipment, essential protective and switching devices and auxiliaries, if any, used for conversion.
operationMode
DCDisconnector
A disconnector within a DC system.
DCEquipmentContainer
A modeling construct to provide a root class for containment of DC as well as AC equipment. The class differ from the EquipmentContaner for AC in that it may also contain DCNodes. Hence it can contain both AC and DC equipment.
DCGround
A ground within a DC system.
inductance
Inductance to ground.
Inductance
Inductive part of reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
r
Resistance to ground.
DCLine
Overhead lines and/or cables connecting two or more HVDC substations.
DCLineSegment
A wire or combination of wires not insulated from one another, with consistent electrical characteristics, used to carry direct current between points in the DC region of the power system.
capacitance
Capacitance of the DC line segment. Significant for cables only.
Capacitance
Capacitive part of reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
inductance
Inductance of the DC line segment. Neglectable compared with DCSeriesDevice used for smoothing.
resistance
Resistance of the DC line segment.
length
Segment length for calculating line section capabilities.
Length
Unit of length. Never negative.
CIMDatatype
value
unit
multiplier
DCNode
DC nodes are points where terminals of DC conducting equipment are connected together with zero impedance.
DCSeriesDevice
A series device within the DC system, typically a reactor used for filtering or smoothing. Needed for transient and short circuit studies.
inductance
Inductance of the device.
resistance
Resistance of the DC device.
ratedUdc
Rated DC device voltage. Converter configuration data used in power flow.
DCShunt
A shunt device within the DC system, typically used for filtering. Needed for transient and short circuit studies.
capacitance
Capacitance of the DC shunt.
resistance
Resistance of the DC device.
ratedUdc
Rated DC device voltage. Converter configuration data used in power flow.
DCSwitch
A switch within the DC system.
DCTerminal
An electrical connection point to generic DC conducting equipment.
PerLengthDCLineParameter
capacitance
Capacitance per unit of length of the DC line segment; significant for cables only.
CapacitancePerLength
Capacitance per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
inductance
Inductance per unit of length of the DC line segment.
InductancePerLength
Inductance per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
resistance
Resistance per length of the DC line segment.
ResistancePerLength
Resistance (real part of impedance) per unit of length.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
VsCapabilityCurve
The P-Q capability curve for a voltage source converter, with P on x-axis and Qmin and Qmax on y1-axis and y2-axis.
VsConverter
DC side of the voltage source converter (VSC).
maxModulationIndex
The max quotient between the AC converter voltage (Uc) and DC voltage (Ud). A factor typically less than 1. VSC configuration data used in power flow.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
maxValveCurrent
The maximum current through a valve. This current limit is the basis for calculating the capability diagram. VSC configuration data.
Topology
BusNameMarker
Used to apply user standard names to topology buses. Typically used for "bus/branch" case generation. Associated with one or more terminals that are normally connected with the bus name. The associated terminals are normally connected by non-retained switches. For a ring bus station configuration, all busbar terminals in the ring are typically associated. For a breaker and a half scheme, both busbars would normally be associated. For a ring bus, all busbars would normally be associated. For a "straight" busbar configuration, normally only the main terminal at the busbar would be associated.
priority
Priority of bus name marker for use as topology bus name. Use 0 for don t care. Use 1 for highest priority. Use 2 as priority is less than 1 and so on.
Meas
Boolean
A type with the value space "true" and "false".
Primitive
DateTime
Date and time as "yyyy-mm-ddThh:mm:ss.sss", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddThh:mm:ss.sssZ". A local timezone relative UTC is specified as "yyyy-mm-ddThh:mm:ss.sss-hh:mm". The second component (shown here as "ss.sss") could have any number of digits in its fractional part to allow any kind of precision beyond seconds.
Primitive
PhaseCode
Enumeration of phase identifiers. Allows designation of phases for both transmission and distribution equipment, circuits and loads.
Residential and small commercial loads are often served from single-phase, or split-phase, secondary circuits. For example of s12N, phases 1 and 2 refer to hot wires that are 180 degrees out of phase, while N refers to the neutral wire. Through single-phase transformer connections, these secondary circuits may be served from one or two of the primary phases A, B, and C. For three-phase loads, use the A, B, C phase codes instead of s12N.
ABCN
Phases A, B, C, and N.
ABC
Phases A, B, and C.
ABN
Phases A, B, and neutral.
ACN
Phases A, C and neutral.
BCN
Phases B, C, and neutral.
AB
Phases A and B.
AC
Phases A and C.
BC
Phases B and C.
AN
Phases A and neutral.
BN
Phases B and neutral.
CN
Phases C and neutral.
A
Phase A.
B
Phase B.
C
Phase C.
N
Neutral phase.
s1N
Secondary phase 1 and neutral.
s2N
Secondary phase 2 and neutral.
s12N
Secondary phases 1, 2, and neutral.
s1
Secondary phase 1.
s2
Secondary phase 2.
s12
Secondary phase 1 and 2.
PerCent
Percentage on a defined base. For example, specify as 100 to indicate at the defined base.
CIMDatatype
value
Normally 0 - 100 on a defined base
unit
multiplier
Source
Source gives information related to the origin of a value.
PROCESS
The value is provided by input from the process I/O or being calculated from some function.
DEFAULTED
The value contains a default value.
SUBSTITUTED
The value is provided by input of an operator or by an automatic source.
Validity
Validity for MeasurementValue.
GOOD
The value is marked good if no abnormal condition of the acquisition function or the information source is detected.
QUESTIONABLE
The value is marked questionable if a supervision function detects an abnormal behaviour, however the value could still be valid. The client is responsible for determining whether or not values marked "questionable" should be used.
INVALID
The value is marked invalid when a supervision function recognises abnormal conditions of the acquisition function or the information source (missing or non-operating updating devices). The value is not defined under this condition. The mark invalid is used to indicate to the client that the value may be incorrect and shall not be used.
Production
The production package is responsible for classes which describe various kinds of generators. These classes also provide production costing information which is used to economically allocate demand among committed units and calculate reserve quantities.
EnergySchedulingType
Used to define the type of generation for scheduling purposes.
Entsoe
EnergySource
A generic equivalent for an energy supplier on a transmission or distribution voltage level.
nominalVoltage
Phase-to-phase nominal voltage.
r
Positive sequence Thevenin resistance.
r0
Zero sequence Thevenin resistance.
rn
Negative sequence Thevenin resistance.
voltageAngle
Phase angle of a-phase open circuit.
AngleRadians
Phase angle in radians.
CIMDatatype
value
unit
multiplier
voltageMagnitude
Phase-to-phase open circuit voltage magnitude.
x
Positive sequence Thevenin reactance.
Reactance
Reactance (imaginary part of impedance), at rated frequency.
CIMDatatype
value
unit
multiplier
x0
Zero sequence Thevenin reactance.
xn
Negative sequence Thevenin reactance.
FossilFuel
The fossil fuel consumed by the non-nuclear thermal generating unit. For example, coal, oil, gas, etc. This a the specific fuels that the generating unit can consume.
fossilFuelType
The type of fossil fuel, such as coal, oil, or gas.
FuelType
Type of fuel.
coal
Generic coal, not including lignite type.
oil
Oil.
gas
Natural gas.
lignite
The fuel is lignite coal. Note that this is a special type of coal, so the other enum of coal is reserved for hard coal types or if the exact type of coal is not known.
hardCoal
Hard coal
oilShale
Oil Shale
GeneratingUnit
A single or set of synchronous machines for converting mechanical power into alternating-current power. For example, individual machines within a set may be defined for scheduling purposes while a single control signal is derived for the set. In this case there would be a GeneratingUnit for each member of the set and an additional GeneratingUnit corresponding to the set.
genControlSource
The source of controls for a generating unit.
GeneratorControlSource
The source of controls for a generating unit.
unavailable
Not available.
offAGC
Off of automatic generation control (AGC).
onAGC
On automatic generation control (AGC).
plantControl
Plant is controlling.
governorSCD
Governor Speed Changer Droop. This is the change in generator power output divided by the change in frequency normalized by the nominal power of the generator and the nominal frequency and expressed in percent and negated. A positive value of speed change droop provides additional generator output upon a drop in frequency.
initialP
Default initial active power which is used to store a powerflow result for the initial active power for this unit in this network configuration.
longPF
Generating unit long term economic participation factor.
maximumAllowableSpinningReserve
Maximum allowable spinning reserve. Spinning reserve will never be considered greater than this value regardless of the current operating point.
maxOperatingP
This is the maximum operating active power limit the dispatcher can enter for this unit.
minOperatingP
This is the minimum operating active power limit the dispatcher can enter for this unit.
nominalP
The nominal power of the generating unit. Used to give precise meaning to percentage based attributes such as the governor speed change droop (governorSCD attribute).
The attribute shall be a positive value equal or less than RotatingMachine.ratedS.
ratedGrossMaxP
The unit's gross rated maximum capacity (book value).
ratedGrossMinP
The gross rated minimum generation level which the unit can safely operate at while delivering power to the transmission grid.
ratedNetMaxP
The net rated maximum capacity determined by subtracting the auxiliary power used to operate the internal plant machinery from the rated gross maximum capacity.
shortPF
Generating unit short term economic participation factor.
startupCost
The initial startup cost incurred for each start of the GeneratingUnit.
Money
Amount of money.
CIMDatatype
unit
Currency
Monetary currencies. Apologies for this list not being exhaustive.
USD
US dollar
EUR
European euro
AUD
Australian dollar
CAD
Canadian dollar
CHF
Swiss francs
CNY
Chinese yuan renminbi
DKK
Danish crown
GBP
British pound
JPY
Japanese yen
NOK
Norwegian crown
RUR
Russian ruble
SEK
Swedish crown
INR
India rupees
other
Another type of currency.
multiplier
value
Decimal
Decimal is the base-10 notational system for representing real numbers.
Primitive
variableCost
The variable cost component of production per unit of ActivePower.
totalEfficiency
The efficiency of the unit in converting the fuel into electrical energy.
HydroEnergyConversionKind
Specifies the capability of the hydro generating unit to convert energy as a generator or pump.
generator
Able to generate power, but not able to pump water for energy storage.
pumpAndGenerator
Able to both generate power and pump water for energy storage.
HydroGeneratingUnit
A generating unit whose prime mover is a hydraulic turbine (e.g., Francis, Pelton, Kaplan).
energyConversionCapability
Energy conversion capability for generating.
HydroPlantStorageKind
The type of hydro power plant.
runOfRiver
Run of river.
pumpedStorage
Pumped storage.
storage
Storage.
HydroPowerPlant
A hydro power station which can generate or pump. When generating, the generator turbines receive water from an upper reservoir. When pumping, the pumps receive their water from a lower reservoir.
hydroPlantStorageType
The type of hydro power plant water storage.
HydroPump
A synchronous motor-driven pump, typically associated with a pumped storage plant.
NuclearGeneratingUnit
A nuclear generating unit.
SolarGeneratingUnit
A solar thermal generating unit.
ThermalGeneratingUnit
A generating unit whose prime mover could be a steam turbine, combustion turbine, or diesel engine.
WindGeneratingUnit
A wind driven generating unit. May be used to represent a single turbine or an aggregation.
windGenUnitType
The kind of wind generating unit
WindGenUnitKind
Kind of wind generating unit.
offshore
The wind generating unit is located offshore.
onshore
The wind generating unit is located onshore.
Core
Contains the core PowerSystemResource and ConductingEquipment entities shared by all applications plus common collections of those entities. Not all applications require all the Core entities. This package does not depend on any other package except the Domain package, but most of the other packages have associations and generalizations that depend on it.
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
sequenceNumber
The orientation of the terminal connections for a multiple terminal conducting equipment. The sequence numbering starts with 1 and additional terminals should follow in increasing order. The first terminal is the "starting point" for a two terminal branch.
BaseVoltage
Defines a system base voltage which is referenced.
nominalVoltage
The power system resource's base voltage.
BasicIntervalSchedule
Schedule of values at points in time.
startTime
The time for the first time point.
value1Unit
Value1 units of measure.
value2Unit
Value2 units of measure.
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
ConnectivityNodeContainer
A base class for all objects that may contain connectivity nodes or topological nodes.
Curve
A multi-purpose curve or functional relationship between an independent variable (X-axis) and dependent (Y-axis) variables.
curveStyle
The style or shape of the curve.
CurveStyle
Style or shape of curve.
constantYValue
The Y-axis values are assumed constant until the next curve point and prior to the first curve point.
straightLineYValues
The Y-axis values are assumed to be a straight line between values. Also known as linear interpolation.
xUnit
The X-axis units of measure.
y1Unit
The Y1-axis units of measure.
y2Unit
The Y2-axis units of measure.
CurveData
Multi-purpose data points for defining a curve. The use of this generic class is discouraged if a more specific class can be used to specify the x and y axis values along with their specific data types.
xvalue
The data value of the X-axis variable, depending on the X-axis units.
y1value
The data value of the first Y-axis variable, depending on the Y-axis units.
y2value
The data value of the second Y-axis variable (if present), depending on the Y-axis units.
Equipment
The parts of a power system that are physical devices, electronic or mechanical.
aggregate
The single instance of equipment represents multiple pieces of equipment that have been modeled together as an aggregate. Examples would be power transformers or synchronous machines operating in parallel modeled as a single aggregate power transformer or aggregate synchronous machine. This is not to be used to indicate equipment that is part of a group of interdependent equipment produced by a network production program.
EquipmentContainer
A modeling construct to provide a root class for containing equipment.
GeographicalRegion
A geographical region of a power system network model.
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
energyIdentCodeEic
Entsoe
The attribute is used for an exchange of the EIC code (Energy identification Code). The length of the string is 16 characters as defined by the EIC code.
References:
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
shortName
Entsoe
The attribute is used for an exchange of a human readable short name with length of the string 12 characters maximum.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
RegularIntervalSchedule
The schedule has time points where the time between them is constant.
timeStep
The time between each pair of subsequent regular time points in sequence order.
Seconds
Time, in seconds.
CIMDatatype
value
Time, in seconds
unit
multiplier
endTime
The time for the last time point.
ReportingGroup
A reporting group is used for various ad-hoc groupings used for reporting.
SubGeographicalRegion
A subset of a geographical region of a power system network model.
Substation
A collection of equipment for purposes other than generation or utilization, through which electric energy in bulk is passed for the purposes of switching or modifying its characteristics.
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
phases
Represents the normal network phasing condition.
If the attribute is missing three phases (ABC or ABCN) shall be assumed.
First_Terminal
The starting terminal for the calculation of distances along the first branch of the mutual coupling. Normally MutualCoupling would only be used for terminals of AC line segments. The first and second terminals of a mutual coupling should point to different AC line segments.
Yes
HasFirstMutualCoupling
Mutual couplings associated with the branch as the first branch.
No
Second_Terminal
The starting terminal for the calculation of distances along the second branch of the mutual coupling.
Yes
HasSecondMutualCoupling
Mutual couplings with the branch associated as the first branch.
No
VoltageLevel
A collection of equipment at one common system voltage forming a switchgear. The equipment typically consist of breakers, busbars, instrumentation, control, regulation and protection devices as well as assemblies of all these.
highVoltageLimit
The bus bar's high voltage limit
lowVoltageLimit
The bus bar's low voltage limit
OperationalLimits
The OperationalLimits package models a specification of limits associated with equipment and other operational entities.
CurrentLimit
Operational limit on current.
value
Limit on current flow.
LimitTypeKind
The enumeration defines the kinds of the limit types.
Entsoe
patl
The Permanent Admissible Transmission Loading (PATL) is the loading in Amps, MVA or MW that can be accepted by a network branch for an unlimited duration without any risk for the material.
The duration attribute is not used and shall be excluded for the PATL limit type. Hence only one limit value exists for the PATL type.
patlt
Permanent Admissible Transmission Loading Threshold (PATLT) is a value in engineering units defined for PATL and calculated using percentage less than 100 of the PATL type intended to alert operators of an arising condition. The percentage should be given in the name of the OperationalLimitSet. The aceptableDuration is another way to express the severity of the limit.
tatl
Temporarily Admissible Transmission Loading (TATL) which is the loading in Amps, MVA or MW that can be accepted by a branch for a certain limited duration.
The TATL can be defined in different ways:
- as a fixed percentage of the PATL for a given time (for example, 115% of the PATL that can be accepted during 15 minutes),
- pairs of TATL type and Duration calculated for each line taking into account its particular configuration and conditions of functioning (for example, it can define a TATL acceptable during 20 minutes and another one acceptable during 10 minutes).
Such a definition of TATL can depend on the initial operating conditions of the network element (sag situation of a line).
The duration attribute can be used define several TATL limit types. Hence multiple TATL limit values may exist having different durations.
tc
Tripping Current (TC) is the ultimate intensity without any delay. It is defined as the threshold the line will trip without any possible remedial actions.
The tripping of the network element is ordered by protections against short circuits or by overload protections, but in any case, the activation delay of these protections is not compatible with the reaction delay of an operator (less than one minute).
The duration is always zero and the duration attribute may be left out. Hence only one limit value exists for the TC type.
tct
Tripping Current Threshold (TCT) is a value in engineering units defined for TC and calculated using percentage less than 100 of the TC type intended to alert operators of an arising condition. The percentage should be given in the name of the OperationalLimitSet. The aceptableDuration is another way to express the severity of the limit.
highVoltage
Referring to the rating of the equipments, a voltage too high can lead to accelerated ageing or the destruction of the equipment.
This limit type may or may not have duration.
lowVoltage
A too low voltage can disturb the normal operation of some protections and transformer equipped with on-load tap changers, electronic power devices or can affect the behaviour of the auxiliaries of generation units.
This limit type may or may not have duration.
OperationalLimit
A value associated with a specific kind of limit.
The sub class value attribute shall be positive.
The sub class value attribute is inversely proportional to OperationalLimitType.acceptableDuration (acceptableDuration for short). A pair of value_x and acceptableDuration_x are related to each other as follows:
if value_1 > value_2 > value_3 >... then
acceptableDuration_1 < acceptableDuration_2 < acceptableDuration_3 < ...
A value_x with direction="high" shall be greater than a value_y with direction="low".
OperationalLimitDirectionKind
The direction attribute describes the side of a limit that is a violation.
high
High means that a monitored value above the limit value is a violation. If applied to a terminal flow, the positive direction is into the terminal.
low
Low means a monitored value below the limit is a violation. If applied to a terminal flow, the positive direction is into the terminal.
absoluteValue
An absoluteValue limit means that a monitored absolute value above the limit value is a violation.
OperationalLimitSet
A set of limits associated with equipment. Sets of limits might apply to a specific temperature, or season for example. A set of limits may contain different severities of limit levels that would apply to the same equipment. The set may contain limits of different types such as apparent power and current limits or high and low voltage limits that are logically applied together as a set.
OperationalLimitType
The operational meaning of a category of limits.
acceptableDuration
The nominal acceptable duration of the limit. Limits are commonly expressed in terms of the a time limit for which the limit is normally acceptable. The actual acceptable duration of a specific limit may depend on other local factors such as temperature or wind speed.
limitType
Entsoe
Types of limits defined in the ENTSO-E Operational Handbook Policy 3.
direction
The direction of the limit.
VoltageLimit
Operational limit applied to voltage.
value
Limit on voltage. High or low limit nature of the limit depends upon the properties of the operational limit type.
Wires
An extension to the Core and Topology package that models information on the electrical characteristics of Transmission and Distribution networks. This package is used by network applications such as State Estimation, Load Flow and Optimal Power Flow.
ACLineSegment
A wire or combination of wires, with consistent electrical characteristics, building a single electrical system, used to carry alternating current between points in the power system.
For symmetrical, transposed 3ph lines, it is sufficient to use attributes of the line segment, which describe impedances and admittances for the entire length of the segment. Additionally impedances can be computed by using length and associated per length impedances.
The BaseVoltage at the two ends of ACLineSegments in a Line shall have the same BaseVoltage.nominalVoltage. However, boundary lines may have slightly different BaseVoltage.nominalVoltages and variation is allowed. Larger voltage difference in general requires use of an equivalent branch.
b0ch
ShortCircuit
Zero sequence shunt (charging) susceptance, uniformly distributed, of the entire line section.
Susceptance
Imaginary part of admittance.
CIMDatatype
value
unit
multiplier
bch
Positive sequence shunt (charging) susceptance, uniformly distributed, of the entire line section. This value represents the full charging over the full length of the line.
g0ch
ShortCircuit
Zero sequence shunt (charging) conductance, uniformly distributed, of the entire line section.
Conductance
Factor by which voltage must be multiplied to give corresponding power lost from a circuit. Real part of admittance.
CIMDatatype
value
unit
multiplier
gch
Positive sequence shunt (charging) conductance, uniformly distributed, of the entire line section.
r
Positive sequence series resistance of the entire line section.
r0
ShortCircuit
Zero sequence series resistance of the entire line section.
shortCircuitEndTemperature
ShortCircuit
Maximum permitted temperature at the end of SC for the calculation of minimum short-circuit currents. Used for short circuit data exchange according to IEC 60909
Temperature
Value of temperature in degrees Celsius.
CIMDatatype
multiplier
unit
value
x
Positive sequence series reactance of the entire line section.
x0
ShortCircuit
Zero sequence series reactance of the entire line section.
AsynchronousMachine
A rotating machine whose shaft rotates asynchronously with the electrical field. Also known as an induction machine with no external connection to the rotor windings, e.g squirrel-cage induction machine.
converterFedDrive
ShortCircuit
Indicates whether the machine is a converter fed drive. Used for short circuit data exchange according to IEC 60909
efficiency
ShortCircuit
Efficiency of the asynchronous machine at nominal operation in percent. Indicator for converter drive motors. Used for short circuit data exchange according to IEC 60909
iaIrRatio
ShortCircuit
Ratio of locked-rotor current to the rated current of the motor (Ia/Ir). Used for short circuit data exchange according to IEC 60909
nominalFrequency
Nameplate data indicates if the machine is 50 or 60 Hz.
Frequency
Cycles per second.
CIMDatatype
value
unit
multiplier
nominalSpeed
Nameplate data. Depends on the slip and number of pole pairs.
RotationSpeed
Number of revolutions per second.
CIMDatatype
value
unit
multiplier
denominatorUnit
denominatorMultiplier
polePairNumber
ShortCircuit
Number of pole pairs of stator. Used for short circuit data exchange according to IEC 60909
ratedMechanicalPower
ShortCircuit
Rated mechanical power (Pr in the IEC 60909-0). Used for short circuit data exchange according to IEC 60909.
reversible
ShortCircuit
Indicates for converter drive motors if the power can be reversible. Used for short circuit data exchange according to IEC 60909
rxLockedRotorRatio
ShortCircuit
Locked rotor ratio (R/X). Used for short circuit data exchange according to IEC 60909
Breaker
A mechanical switching device capable of making, carrying, and breaking currents under normal circuit conditions and also making, carrying for a specified time, and breaking currents under specified abnormal circuit conditions e.g. those of short circuit.
BusbarSection
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation.
Voltage measurements are typically obtained from VoltageTransformers that are connected to busbar sections. A bus bar section may have many physical terminals but for analysis is modelled with exactly one logical terminal.
ipMax
ShortCircuit
Maximum allowable peak short-circuit current of busbar (Ipmax in the IEC 60909-0).
Mechanical limit of the busbar in the substation itself. Used for short circuit data exchange according to IEC 60909
Conductor
Combination of conducting material with consistent electrical characteristics, building a single electrical system, used to carry current between points in the power system.
length
Segment length for calculating line section capabilities
Connector
A conductor, or group of conductors, with negligible impedance, that serve to connect other conducting equipment within a single substation and are modelled with a single logical terminal.
Disconnector
A manually operated or motor operated mechanical switching device used for changing the connections in a circuit, or for isolating a circuit or equipment from a source of power. It is required to open or close circuits when negligible current is broken or made.
EarthFaultCompensator
A conducting equipment used to represent a connection to ground which is typically used to compensate earth faults.. An earth fault compensator device modeled with a single terminal implies a second terminal solidly connected to ground. If two terminals are modeled, the ground is not assumed and normal connection rules apply.
ShortCircuit
r
Nominal resistance of device.
EnergyConsumer
Generic user of energy - a point of consumption on the power system model.
ReactivePower
Product of RMS value of the voltage and the RMS value of the quadrature component of the current.
CIMDatatype
value
unit
multiplier
ExternalNetworkInjection
This class represents external network and it is used for IEC 60909 calculations.
governorSCD
Power Frequency Bias. This is the change in power injection divided by the change in frequency and negated. A positive value of the power frequency bias provides additional power injection upon a drop in frequency.
ActivePowerPerFrequency
Active power variation with frequency.
CIMDatatype
denominatorMultiplier
denominatorUnit
multiplier
unit
value
ikSecond
ShortCircuit
Indicates whether initial symmetrical short-circuit current and power have been calculated according to IEC (Ik").
maxInitialSymShCCurrent
ShortCircuit
Maximum initial symmetrical short-circuit currents (Ik" max) in A (Ik" = Sk"/(SQRT(3) Un)). Used for short circuit data exchange according to IEC 60909
maxP
Maximum active power of the injection.
maxQ
Not for short circuit modelling; It is used for modelling of infeed for load flow exchange. If maxQ and minQ are not used ReactiveCapabilityCurve can be used
maxR0ToX0Ratio
ShortCircuit
Maximum ratio of zero sequence resistance of Network Feeder to its zero sequence reactance (R(0)/X(0) max). Used for short circuit data exchange according to IEC 60909
maxR1ToX1Ratio
ShortCircuit
Maximum ratio of positive sequence resistance of Network Feeder to its positive sequence reactance (R(1)/X(1) max). Used for short circuit data exchange according to IEC 60909
maxZ0ToZ1Ratio
ShortCircuit
Maximum ratio of zero sequence impedance to its positive sequence impedance (Z(0)/Z(1) max). Used for short circuit data exchange according to IEC 60909
minInitialSymShCCurrent
ShortCircuit
Minimum initial symmetrical short-circuit currents (Ik" min) in A (Ik" = Sk"/(SQRT(3) Un)). Used for short circuit data exchange according to IEC 60909
minP
Minimum active power of the injection.
minQ
Not for short circuit modelling; It is used for modelling of infeed for load flow exchange. If maxQ and minQ are not used ReactiveCapabilityCurve can be used
minR0ToX0Ratio
ShortCircuit
Indicates whether initial symmetrical short-circuit current and power have been calculated according to IEC (Ik"). Used for short circuit data exchange according to IEC 6090
minR1ToX1Ratio
ShortCircuit
Minimum ratio of positive sequence resistance of Network Feeder to its positive sequence reactance (R(1)/X(1) min). Used for short circuit data exchange according to IEC 60909
minZ0ToZ1Ratio
ShortCircuit
Minimum ratio of zero sequence impedance to its positive sequence impedance (Z(0)/Z(1) min). Used for short circuit data exchange according to IEC 60909
voltageFactor
ShortCircuit
Voltage factor in pu, which was used to calculate short-circuit current Ik" and power Sk".
PU
Per Unit - a positive or negative value referred to a defined base. Values typically range from -10 to +10.
CIMDatatype
value
unit
multiplier
Ground
A point where the system is grounded used for connecting conducting equipment to ground. The power system model can have any number of grounds.
ShortCircuit
Operation
GroundDisconnector
A manually operated or motor operated mechanical switching device used for isolating a circuit or equipment from ground.
ShortCircuit
Operation
GroundingImpedance
A fixed impedance device used for grounding.
ShortCircuit
x
Reactance of device.
Junction
A point where one or more conducting equipments are connected with zero resistance.
Line
Contains equipment beyond a substation belonging to a power transmission line.
LinearShuntCompensator
A linear shunt compensator has banks or sections with equal admittance values.
b0PerSection
ShortCircuit
Zero sequence shunt (charging) susceptance per section
bPerSection
Positive sequence shunt (charging) susceptance per section
g0PerSection
ShortCircuit
Zero sequence shunt (charging) conductance per section
gPerSection
Positive sequence shunt (charging) conductance per section
LoadBreakSwitch
A mechanical switching device capable of making, carrying, and breaking currents under normal operating conditions.
MutualCoupling
This class represents the zero sequence line mutual coupling.
ShortCircuit
b0ch
Zero sequence mutual coupling shunt (charging) susceptance, uniformly distributed, of the entire line section.
distance11
Distance to the start of the coupled region from the first line's terminal having sequence number equal to 1.
distance12
Distance to the end of the coupled region from the first line's terminal with sequence number equal to 1.
distance21
Distance to the start of coupled region from the second line's terminal with sequence number equal to 1.
distance22
Distance to the end of coupled region from the second line's terminal with sequence number equal to 1.
g0ch
Zero sequence mutual coupling shunt (charging) conductance, uniformly distributed, of the entire line section.
r0
Zero sequence branch-to-branch mutual impedance coupling, resistance.
x0
Zero sequence branch-to-branch mutual impedance coupling, reactance.
NonlinearShuntCompensator
A non linear shunt compensator has bank or section admittance values that differs.
NonlinearShuntCompensatorPoint
A non linear shunt compensator bank or section admittance value.
b
Positive sequence shunt (charging) susceptance per section
b0
ShortCircuit
Zero sequence shunt (charging) susceptance per section
g
Positive sequence shunt (charging) conductance per section
g0
ShortCircuit
Zero sequence shunt (charging) conductance per section
sectionNumber
The number of the section.
PetersenCoil
A tunable impedance device normally used to offset line charging during single line faults in an ungrounded section of network.
ShortCircuit
mode
The mode of operation of the Petersen coil.
PetersenCoilModeKind
The mode of operation for a Petersen coil.
fixed
Fixed position.
manual
Manual positioning.
automaticPositioning
Automatic positioning.
nominalU
The nominal voltage for which the coil is designed.
offsetCurrent
The offset current that the Petersen coil controller is operating from the resonant point. This is normally a fixed amount for which the controller is configured and could be positive or negative. Typically 0 to 60 Amperes depending on voltage and resonance conditions.
positionCurrent
The control current used to control the Petersen coil also known as the position current. Typically in the range of 20-200mA.
xGroundMax
The maximum reactance.
xGroundMin
The minimum reactance.
xGroundNominal
The nominal reactance. This is the operating point (normally over compensation) that is defined based on the resonance point in the healthy network condition. The impedance is calculated based on nominal voltage divided by position current.
PhaseTapChanger
A transformer phase shifting tap model that controls the phase angle difference across the power transformer and potentially the active power flow through the power transformer. This phase tap model may also impact the voltage magnitude.
PhaseTapChangerAsymmetrical
Describes the tap model for an asymmetrical phase shifting transformer in which the difference voltage vector adds to the primary side voltage. The angle between the primary side voltage and the difference voltage is named the winding connection angle. The phase shift depends on both the difference voltage magnitude and the winding connection angle.
windingConnectionAngle
The phase angle between the in-phase winding and the out-of -phase winding used for creating phase shift. The out-of-phase winding produces what is known as the difference voltage. Setting this angle to 90 degrees is not the same as a symmemtrical transformer.
PhaseTapChangerLinear
Describes a tap changer with a linear relation between the tap step and the phase angle difference across the transformer. This is a mathematical model that is an approximation of a real phase tap changer.
The phase angle is computed as stepPhaseShitfIncrement times the tap position.
The secondary side voltage magnitude is the same as at the primary side.
stepPhaseShiftIncrement
Phase shift per step position. A positive value indicates a positive phase shift from the winding where the tap is located to the other winding (for a two-winding transformer).
The actual phase shift increment might be more accurately computed from the symmetrical or asymmetrical models or a tap step table lookup if those are available.
xMax
The reactance depend on the tap position according to a "u" shaped curve. The maximum reactance (xMax) appear at the low and high tap positions.
xMin
The reactance depend on the tap position according to a "u" shaped curve. The minimum reactance (xMin) appear at the mid tap position.
PhaseTapChangerNonLinear
The non-linear phase tap changer describes the non-linear behavior of a phase tap changer. This is a base class for the symmetrical and asymmetrical phase tap changer models. The details of these models can be found in the IEC 61970-301 document.
voltageStepIncrement
The voltage step increment on the out of phase winding specified in percent of nominal voltage of the transformer end.
xMax
The reactance depend on the tap position according to a "u" shaped curve. The maximum reactance (xMax) appear at the low and high tap positions.
xMin
The reactance depend on the tap position according to a "u" shaped curve. The minimum reactance (xMin) appear at the mid tap position.
PhaseTapChangerSymmetrical
Describes a symmetrical phase shifting transformer tap model in which the secondary side voltage magnitude is the same as at the primary side. The difference voltage magnitude is the base in an equal-sided triangle where the sides corresponds to the primary and secondary voltages. The phase angle difference corresponds to the top angle and can be expressed as twice the arctangent of half the total difference voltage.
PhaseTapChangerTable
Describes a tabular curve for how the phase angle difference and impedance varies with the tap step.
PhaseTapChangerTablePoint
Describes each tap step in the phase tap changer tabular curve.
angle
The angle difference in degrees.
PhaseTapChangerTabular
PowerTransformer
An electrical device consisting of two or more coupled windings, with or without a magnetic core, for introducing mutual coupling between electric circuits. Transformers can be used to control voltage and phase shift (active power flow).
A power transformer may be composed of separate transformer tanks that need not be identical.
A power transformer can be modeled with or without tanks and is intended for use in both balanced and unbalanced representations. A power transformer typically has two terminals, but may have one (grounding), three or more terminals.
The inherited association ConductingEquipment.BaseVoltage should not be used. The association from TransformerEnd to BaseVoltage should be used instead.
beforeShCircuitHighestOperatingCurrent
ShortCircuit
The highest operating current (Ib in the IEC 60909-0) before short circuit (depends on network configuration and relevant reliability philosophy). It is used for calculation of the impedance correction factor KT defined in IEC 60909-0.
beforeShCircuitHighestOperatingVoltage
ShortCircuit
The highest operating voltage (Ub in the IEC 60909-0) before short circuit. It is used for calculation of the impedance correction factor KT defined in IEC 60909-0. This is worst case voltage on the low side winding (Section 3.7.1 in the standard). Used to define operating conditions.
beforeShortCircuitAnglePf
ShortCircuit
The angle of power factor before short circuit (phib in the IEC 60909-0). It is used for calculation of the impedance correction factor KT defined in IEC 60909-0. This is the worst case power factor. Used to define operating conditions.
highSideMinOperatingU
ShortCircuit
The minimum operating voltage (uQmin in the IEC 60909-0) at the high voltage side (Q side) of the unit transformer of the power station unit. A value well established from long-term operating experience of the system. It is used for calculation of the impedance correction factor KG defined in IEC 60909-0
isPartOfGeneratorUnit
ShortCircuit
Indicates whether the machine is part of a power station unit. Used for short circuit data exchange according to IEC 60909
operationalValuesConsidered
ShortCircuit
It is used to define if the data (other attributes related to short circuit data exchange) defines long term operational conditions or not. Used for short circuit data exchange according to IEC 60909.
PowerTransformerEnd
A PowerTransformerEnd is associated with each Terminal of a PowerTransformer.
The impedance values r, r0, x, and x0 of a PowerTransformerEnd represents a star equivalent as follows
1) for a two Terminal PowerTransformer the high voltage PowerTransformerEnd has non zero values on r, r0, x, and x0 while the low voltage PowerTransformerEnd has zero values for r, r0, x, and x0.
2) for a three Terminal PowerTransformer the three PowerTransformerEnds represents a star equivalent with each leg in the star represented by r, r0, x, and x0 values.
3) for a PowerTransformer with more than three Terminals the PowerTransformerEnd impedance values cannot be used. Instead use the TransformerMeshImpedance or split the transformer into multiple PowerTransformers.
b
Magnetizing branch susceptance (B mag). The value can be positive or negative.
connectionKind
Kind of connection.
WindingConnection
Winding connection type.
D
Delta
Y
Wye
Z
ZigZag
Yn
Wye, with neutral brought out for grounding.
Zn
ZigZag, with neutral brought out for grounding.
A
Autotransformer common winding
I
Independent winding, for single-phase connections
b0
ShortCircuit
Zero sequence magnetizing branch susceptance.
phaseAngleClock
ShortCircuit
Terminal voltage phase angle displacement where 360 degrees are represented with clock hours. The valid values are 0 to 11. For example, for the secondary side end of a transformer with vector group code of 'Dyn11', specify the connection kind as wye with neutral and specify the phase angle of the clock as 11. The clock value of the transformer end number specified as 1, is assumed to be zero. Note the transformer end number is not assumed to be the same as the terminal sequence number.
ratedS
Normal apparent power rating.
The attribute shall be a positive value. For a two-winding transformer the values for the high and low voltage sides shall be identical.
g
Magnetizing branch conductance.
ratedU
Rated voltage: phase-phase for three-phase windings, and either phase-phase or phase-neutral for single-phase windings.
A high voltage side, as given by TransformerEnd.endNumber, shall have a ratedU that is greater or equal than ratedU for the lower voltage sides.
g0
ShortCircuit
Zero sequence magnetizing branch conductance (star-model).
r
Resistance (star-model) of the transformer end.
The attribute shall be equal or greater than zero for non-equivalent transformers.
r0
ShortCircuit
Zero sequence series resistance (star-model) of the transformer end.
x
Positive sequence series reactance (star-model) of the transformer end.
x0
ShortCircuit
Zero sequence series reactance of the transformer end.
ProtectedSwitch
A ProtectedSwitch is a switching device that can be operated by ProtectionEquipment.
RatioTapChanger
A tap changer that changes the voltage ratio impacting the voltage magnitude but not the phase angle across the transformer.
tculControlMode
Specifies the regulation control mode (voltage or reactive) of the RatioTapChanger.
TransformerControlMode
Control modes for a transformer.
volt
Voltage control
reactive
Reactive power flow control
stepVoltageIncrement
Tap step increment, in per cent of nominal voltage, per step position.
RatioTapChangerTable
Describes a curve for how the voltage magnitude and impedance varies with the tap step.
RatioTapChangerTablePoint
Describes each tap step in the ratio tap changer tabular curve.
ReactiveCapabilityCurve
Reactive power rating envelope versus the synchronous machine's active power, in both the generating and motoring modes. For each active power value there is a corresponding high and low reactive power limit value. Typically there will be a separate curve for each coolant condition, such as hydrogen pressure. The Y1 axis values represent reactive minimum and the Y2 axis values represent reactive maximum.
RegulatingCondEq
A type of conducting equipment that can regulate a quantity (i.e. voltage or flow) at a specific point in the network.
RegulatingControl
Specifies a set of equipment that works together to control a power system quantity such as voltage or flow.
Remote bus voltage control is possible by specifying the controlled terminal located at some place remote from the controlling equipment.
In case multiple equipment, possibly of different types, control same terminal there must be only one RegulatingControl at that terminal. The most specific subtype of RegulatingControl shall be used in case such equipment participate in the control, e.g. TapChangerControl for tap changers.
For flow control load sign convention is used, i.e. positive sign means flow out from a TopologicalNode (bus) into the conducting equipment.
mode
The regulating control mode presently available. This specification allows for determining the kind of regulation without need for obtaining the units from a schedule.
RegulatingControlModeKind
The kind of regulation model. For example regulating voltage, reactive power, active power, etc.
voltage
Voltage is specified.
activePower
Active power is specified.
reactivePower
Reactive power is specified.
currentFlow
Current flow is specified.
admittance
Admittance is specified.
timeScheduled
Control switches on/off by time of day. The times may change on the weekend, or in different seasons.
temperature
Control switches on/off based on the local temperature (i.e., a thermostat).
powerFactor
Power factor is specified.
RotatingMachine
A rotating machine which may be used as a generator or motor.
ratedPowerFactor
Power factor (nameplate data). It is primarily used for short circuit data exchange according to IEC 60909.
ratedS
Nameplate apparent power rating for the unit.
The attribute shall have a positive value.
ratedU
Rated voltage (nameplate data, Ur in IEC 60909-0). It is primarily used for short circuit data exchange according to IEC 60909.
SeriesCompensator
A Series Compensator is a series capacitor or reactor or an AC transmission line without charging susceptance. It is a two terminal device.
r
Positive sequence resistance.
r0
ShortCircuit
Zero sequence resistance.
x
Positive sequence reactance.
x0
ShortCircuit
Zero sequence reactance.
varistorPresent
Describe if a metal oxide varistor (mov) for over voltage protection is configured at the series compensator.
varistorRatedCurrent
The maximum current the varistor is designed to handle at specified duration.
varistorVoltageThreshold
The dc voltage at which the varistor start conducting.
ShortCircuitRotorKind
Type of rotor, used by short circuit applications.
salientPole1
Salient pole 1 in the IEC 60909
salientPole2
Salient pole 2 in IEC 60909
turboSeries1
Turbo Series 1 in the IEC 60909
turboSeries2
Turbo series 2 in IEC 60909
ShuntCompensator
A shunt capacitor or reactor or switchable bank of shunt capacitors or reactors. A section of a shunt compensator is an individual capacitor or reactor. A negative value for reactivePerSection indicates that the compensator is a reactor. ShuntCompensator is a single terminal device. Ground is implied.
aVRDelay
Time delay required for the device to be connected or disconnected by automatic voltage regulation (AVR).
grounded
Used for Yn and Zn connections. True if the neutral is solidly grounded.
maximumSections
The maximum number of sections that may be switched in.
nomU
The voltage at which the nominal reactive power may be calculated. This should normally be within 10% of the voltage at which the capacitor is connected to the network.
normalSections
The normal number of sections switched in.
switchOnCount
The switch on count since the capacitor count was last reset or initialized.
switchOnDate
The date and time when the capacitor bank was last switched on.
voltageSensitivity
Voltage sensitivity required for the device to regulate the bus voltage, in voltage/reactive power.
VoltagePerReactivePower
Voltage variation with reactive power.
CIMDatatype
value
unit
denominatorMultiplier
multiplier
denominatorUnit
StaticVarCompensator
A facility for providing variable and controllable shunt reactive power. The SVC typically consists of a stepdown transformer, filter, thyristor-controlled reactor, and thyristor-switched capacitor arms.
The SVC may operate in fixed MVar output mode or in voltage control mode. When in voltage control mode, the output of the SVC will be proportional to the deviation of voltage at the controlled bus from the voltage setpoint. The SVC characteristic slope defines the proportion. If the voltage at the controlled bus is equal to the voltage setpoint, the SVC MVar output is zero.
capacitiveRating
Maximum available capacitive reactance.
inductiveRating
Maximum available inductive reactance.
slope
The characteristics slope of an SVC defines how the reactive power output changes in proportion to the difference between the regulated bus voltage and the voltage setpoint.
sVCControlMode
SVC control mode.
SVCControlMode
Static VAr Compensator control mode.
reactivePower
voltage
voltageSetPoint
The reactive power output of the SVC is proportional to the difference between the voltage at the regulated bus and the voltage setpoint. When the regulated bus voltage is equal to the voltage setpoint, the reactive power output is zero.
Switch
A generic device designed to close, or open, or both, one or more electric circuits. All switches are two terminal devices including grounding switches.
normalOpen
The attribute is used in cases when no Measurement for the status value is present. If the Switch has a status measurement the Discrete.normalValue is expected to match with the Switch.normalOpen.
ratedCurrent
The maximum continuous current carrying capacity in amps governed by the device material and construction.
retained
Branch is retained in a bus branch model. The flow through retained switches will normally be calculated in power flow.
SynchronousMachine
An electromechanical device that operates with shaft rotating synchronously with the network. It is a single machine operating either as a generator or synchronous condenser or pump.
earthing
ShortCircuit
Indicates whether or not the generator is earthed. Used for short circuit data exchange according to IEC 60909
earthingStarPointR
ShortCircuit
Generator star point earthing resistance (Re). Used for short circuit data exchange according to IEC 60909
earthingStarPointX
ShortCircuit
Generator star point earthing reactance (Xe). Used for short circuit data exchange according to IEC 60909
ikk
ShortCircuit
Steady-state short-circuit current (in A for the profile) of generator with compound excitation during 3-phase short circuit.
- Ikk=0: Generator with no compound excitation.
- Ikk?0: Generator with compound excitation.
Ikk is used to calculate the minimum steady-state short-circuit current for generators with compound excitation
(Section 4.6.1.2 in the IEC 60909-0)
Used only for single fed short circuit on a generator. (Section 4.3.4.2. in the IEC 60909-0)
maxQ
Maximum reactive power limit. This is the maximum (nameplate) limit for the unit.
minQ
Minimum reactive power limit for the unit.
mu
ShortCircuit
Factor to calculate the breaking current (Section 4.5.2.1 in the IEC 60909-0).
Used only for single fed short circuit on a generator (Section 4.3.4.2. in the IEC 60909-0).
qPercent
Percent of the coordinated reactive control that comes from this machine.
r0
ShortCircuit
Zero sequence resistance of the synchronous machine.
r2
ShortCircuit
Negative sequence resistance.
satDirectSubtransX
ShortCircuit
Direct-axis subtransient reactance saturated, also known as Xd"sat.
satDirectSyncX
ShortCircuit
Direct-axes saturated synchronous reactance (xdsat); reciprocal of short-circuit ration. Used for short circuit data exchange, only for single fed short circuit on a generator. (Section 4.3.4.2. in the IEC 60909-0).
satDirectTransX
ShortCircuit
Saturated Direct-axis transient reactance. The attribute is primarily used for short circuit calculations according to ANSI.
shortCircuitRotorType
ShortCircuit
Type of rotor, used by short circuit applications, only for single fed short circuit according to IEC 60909.
type
Modes that this synchronous machine can operate in.
SynchronousMachineKind
Synchronous machine type.
generator
condenser
generatorOrCondenser
motor
generatorOrMotor
motorOrCondenser
generatorOrCondenserOrMotor
voltageRegulationRange
ShortCircuit
Range of generator voltage regulation (PG in the IEC 60909-0) used for calculation of the impedance correction factor KG defined in IEC 60909-0
This attribute is used to describe the operating voltage of the generating unit.
r
ShortCircuit
Equivalent resistance (RG) of generator. RG is considered for the calculation of all currents, except for the calculation of the peak current ip. Used for short circuit data exchange according to IEC 60909
x0
ShortCircuit
Zero sequence reactance of the synchronous machine.
x2
ShortCircuit
Negative sequence reactance.
TapChanger
Mechanism for changing transformer winding tap positions.
highStep
Highest possible tap step position, advance from neutral.
The attribute shall be greater than lowStep.
lowStep
Lowest possible tap step position, retard from neutral
ltcFlag
Specifies whether or not a TapChanger has load tap changing capabilities.
neutralStep
The neutral tap step position for this winding.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
neutralU
Voltage at which the winding operates at the neutral tap setting.
normalStep
The tap step position used in "normal" network operation for this winding. For a "Fixed" tap changer indicates the current physical tap setting.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
TapChangerControl
Describes behavior specific to tap changers, e.g. how the voltage at the end of a line varies with the load level and compensation of the voltage drop by tap adjustment.
TapChangerTablePoint
b
The magnetizing branch susceptance deviation in percent of nominal value. The actual susceptance is calculated as follows:
calculated magnetizing susceptance = b(nominal) * (1 + b(from this class)/100). The b(nominal) is defined as the static magnetizing susceptance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
g
The magnetizing branch conductance deviation in percent of nominal value. The actual conductance is calculated as follows:
calculated magnetizing conductance = g(nominal) * (1 + g(from this class)/100). The g(nominal) is defined as the static magnetizing conductance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
r
The resistance deviation in percent of nominal value. The actual reactance is calculated as follows:
calculated resistance = r(nominal) * (1 + r(from this class)/100). The r(nominal) is defined as the static resistance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
ratio
The voltage ratio in per unit. Hence this is a value close to one.
step
The tap step.
x
The series reactance deviation in percent of nominal value. The actual reactance is calculated as follows:
calculated reactance = x(nominal) * (1 + x(from this class)/100). The x(nominal) is defined as the static series reactance on the associated power transformer end or ends. This model assumes the star impedance (pi model) form.
TransformerEnd
A conducting connection point of a power transformer. It corresponds to a physical transformer winding terminal. In earlier CIM versions, the TransformerWinding class served a similar purpose, but this class is more flexible because it associates to terminal but is not a specialization of ConductingEquipment.
rground
ShortCircuit
(for Yn and Zn connections) Resistance part of neutral impedance where 'grounded' is true.
endNumber
Number for this transformer end, corresponding to the end's order in the power transformer vector group or phase angle clock number. Highest voltage winding should be 1. Each end within a power transformer should have a unique subsequent end number. Note the transformer end number need not match the terminal sequence number.
grounded
ShortCircuit
(for Yn and Zn connections) True if the neutral is solidly grounded.
xground
ShortCircuit
(for Yn and Zn connections) Reactive part of neutral impedance where 'grounded' is true.
LoadModel
This package is responsible for modeling the energy consumers and the system load as curves and associated curve data. Special circumstances that may affect the load, such as seasons and daytypes, are also included here.
This information is used by Load Forecasting and Load Management.
ConformLoad
ConformLoad represent loads that follow a daily load change pattern where the pattern can be used to scale the load with a system load.
ConformLoadGroup
A group of loads conforming to an allocation pattern.
ConformLoadSchedule
A curve of load versus time (X-axis) showing the active power values (Y1-axis) and reactive power (Y2-axis) for each unit of the period covered. This curve represents a typical pattern of load over the time period for a given day type and season.
LoadGroup
The class is the third level in a hierarchical structure for grouping of loads for the purpose of load flow load scaling.
LoadResponseCharacteristic
Models the characteristic response of the load demand due to changes in system conditions such as voltage and frequency. This is not related to demand response.
If LoadResponseCharacteristic.exponentModel is True, the voltage exponents are specified and used as to calculate:
Active power component = Pnominal * (Voltage/cim:BaseVoltage.nominalVoltage) ** cim:LoadResponseCharacteristic.pVoltageExponent
Reactive power component = Qnominal * (Voltage/cim:BaseVoltage.nominalVoltage)** cim:LoadResponseCharacteristic.qVoltageExponent
Where * means "multiply" and ** is "raised to power of".
exponentModel
Indicates the exponential voltage dependency model is to be used. If false, the coefficient model is to be used.
The exponential voltage dependency model consist of the attributes
- pVoltageExponent
- qVoltageExponent.
The coefficient model consist of the attributes
- pConstantImpedance
- pConstantCurrent
- pConstantPower
- qConstantImpedance
- qConstantCurrent
- qConstantPower.
The sum of pConstantImpedance, pConstantCurrent and pConstantPower shall equal 1.
The sum of qConstantImpedance, qConstantCurrent and qConstantPower shall equal 1.
pConstantCurrent
Portion of active power load modeled as constant current.
pConstantImpedance
Portion of active power load modeled as constant impedance.
pConstantPower
Portion of active power load modeled as constant power.
pFrequencyExponent
Exponent of per unit frequency effecting active power.
pVoltageExponent
Exponent of per unit voltage effecting real power.
qConstantCurrent
Portion of reactive power load modeled as constant current.
qConstantImpedance
Portion of reactive power load modeled as constant impedance.
qConstantPower
Portion of reactive power load modeled as constant power.
qFrequencyExponent
Exponent of per unit frequency effecting reactive power.
qVoltageExponent
Exponent of per unit voltage effecting reactive power.
NonConformLoad
NonConformLoad represent loads that do not follow a daily load change pattern and changes are not correlated with the daily load change pattern.
NonConformLoadGroup
Loads that do not follow a daily and seasonal load variation pattern.
NonConformLoadSchedule
An active power (Y1-axis) and reactive power (Y2-axis) schedule (curves) versus time (X-axis) for non-conforming loads, e.g., large industrial load or power station service (where modeled).
MonthDay
MonthDay format as "--mm-dd", which conforms with XSD data type gMonthDay.
Primitive
Equivalents
The equivalents package models equivalent networks.
EquivalentBranch
The class represents equivalent branches.
negativeR12
ShortCircuit
Negative sequence series resistance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
EquivalentBranch is a result of network reduction prior to the data exchange
negativeR21
ShortCircuit
Negative sequence series resistance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
EquivalentBranch is a result of network reduction prior to the data exchange
negativeX12
ShortCircuit
Negative sequence series reactance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
negativeX21
ShortCircuit
Negative sequence series reactance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909.
Usage: EquivalentBranch is a result of network reduction prior to the data exchange
positiveR12
ShortCircuit
Positive sequence series resistance from terminal sequence 1 to terminal sequence 2 . Used for short circuit data exchange according to IEC 60909.
EquivalentBranch is a result of network reduction prior to the data exchange.
positiveR21
ShortCircuit
Positive sequence series resistance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
EquivalentBranch is a result of network reduction prior to the data exchange
positiveX12
ShortCircuit
Positive sequence series reactance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
positiveX21
ShortCircuit
Positive sequence series reactance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
r
Positive sequence series resistance of the reduced branch.
r21
Resistance from terminal sequence 2 to terminal sequence 1 .Used for steady state power flow. This attribute is optional and represent unbalanced network such as off-nominal phase shifter. If only EquivalentBranch.r is given, then EquivalentBranch.r21 is assumed equal to EquivalentBranch.r.
Usage rule : EquivalentBranch is a result of network reduction prior to the data exchange.
x
Positive sequence series reactance of the reduced branch.
x21
Reactance from terminal sequence 2 to terminal sequence 1 .Used for steady state power flow. This attribute is optional and represent unbalanced network such as off-nominal phase shifter. If only EquivalentBranch.x is given, then EquivalentBranch.x21 is assumed equal to EquivalentBranch.x.
Usage rule : EquivalentBranch is a result of network reduction prior to the data exchange.
zeroR12
ShortCircuit
Zero sequence series resistance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
EquivalentBranch is a result of network reduction prior to the data exchange
zeroR21
ShortCircuit
Zero sequence series resistance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
zeroX12
ShortCircuit
Zero sequence series reactance from terminal sequence 1 to terminal sequence 2. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
zeroX21
ShortCircuit
Zero sequence series reactance from terminal sequence 2 to terminal sequence 1. Used for short circuit data exchange according to IEC 60909
Usage : EquivalentBranch is a result of network reduction prior to the data exchange
EquivalentEquipment
The class represents equivalent objects that are the result of a network reduction. The class is the base for equivalent objects of different types.
EquivalentInjection
This class represents equivalent injections (generation or load). Voltage regulation is allowed only at the point of connection.
maxP
Maximum active power of the injection.
maxQ
Used for modeling of infeed for load flow exchange. Not used for short circuit modeling. If maxQ and minQ are not used ReactiveCapabilityCurve can be used.
minP
Minimum active power of the injection.
minQ
Used for modeling of infeed for load flow exchange. Not used for short circuit modeling. If maxQ and minQ are not used ReactiveCapabilityCurve can be used.
r
ShortCircuit
Positive sequence resistance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
r0
ShortCircuit
Zero sequence resistance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
r2
ShortCircuit
Negative sequence resistance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
regulationCapability
Specifies whether or not the EquivalentInjection has the capability to regulate the local voltage.
x
ShortCircuit
Positive sequence reactance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
x0
ShortCircuit
Zero sequence reactance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
x2
ShortCircuit
Negative sequence reactance. Used to represent Extended-Ward (IEC 60909).
Usage : Extended-Ward is a result of network reduction prior to the data exchange.
EquivalentNetwork
A class that represents an external meshed network that has been reduced to an electrically equivalent model. The ConnectivityNodes contained in the equivalent are intended to reflect internal nodes of the equivalent. The boundary Connectivity nodes where the equivalent connects outside itself are NOT contained by the equivalent.
EquivalentShunt
The class represents equivalent shunts.
b
Positive sequence shunt susceptance.
g
Positive sequence shunt conductance.
ControlArea
The ControlArea package models area specifications which can be used for a variety of purposes. The package as a whole models potentially overlapping control area specifications for the purpose of actual generation control, load forecast area load capture, or powerflow based analysis.
ControlArea
A control area is a grouping of generating units and/or loads and a cutset of tie lines (as terminals) which may be used for a variety of purposes including automatic generation control, powerflow solution area interchange control specification, and input to load forecasting. Note that any number of overlapping control area specifications can be superimposed on the physical model.
type
The primary type of control area definition used to determine if this is used for automatic generation control, for planning interchange control, or other purposes. A control area specified with primary type of automatic generation control could still be forecast and used as an interchange area in power flow analysis.
ControlAreaTypeKind
The type of control area.
AGC
Used for automatic generation control.
Forecast
Used for load forecast.
Interchange
Used for interchange specification or control.
ControlAreaGeneratingUnit
A control area generating unit. This class is needed so that alternate control area definitions may include the same generating unit. Note only one instance within a control area should reference a specific generating unit.
TieFlow
A flow specification in terms of location and direction for a control area.
positiveFlowIn
True if the flow into the terminal (load convention) is also flow into the control area. For example, this attribute should be true if using the tie line terminal further away from the control area. For example to represent a tie to a shunt component (like a load or generator) in another area, this is the near end of a branch and this attribute would be specified as false.
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GeographicalLocationProfile
This geographical location profile is built on the basis of the IEC profile. There is small difference in one association which is specific for exchanges between TSOs.
GeographicalLocationVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURI
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/GeographicalLocation/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
Common
CoordinateSystem
Coordinate reference system.
crsUrn
A Uniform Resource Name (URN) for the coordinate reference system (crs) used to define 'Location.PositionPoints'.
An example would be the European Petroleum Survey Group (EPSG) code for a coordinate reference system, defined in URN under the Open Geospatial Consortium (OGC) namespace as: urn:ogc:def:uom:EPSG::XXXX, where XXXX is an EPSG code (a full list of codes can be found at the EPSG Registry web site http://www.epsg-registry.org/). To define the coordinate system as being WGS84 (latitude, longitude) using an EPSG OGC, this attribute would be urn:ogc:def:uom:EPSG::4236.
A profile should limit this code to a set of allowed URNs agreed to by all sending and receiving parties.
CoordinateSystem
Coordinate system used to describe position points of this location.
Yes
Location
All locations described with position points in this coordinate system.
Location
No
Location
The place, scene, or point of something where someone or something has been, is, and/or will be at a given moment in time. It can be defined with one or more postition points (coordinates) in a given coordinate system.
PowerSystemResources
All power system resources at this location.
Yes
Location
Location of this power system resource.
Location
No
PositionPoints
Sequence of position points describing this location, expressed in coordinate system 'Location.CoordinateSystem'.
No
Location
Location described by this position point.
Location
Yes
PositionPoint
Set of spatial coordinates that determine a point, defined in the coordinate system specified in 'Location.CoordinateSystem'. Use a single position point instance to desribe a point-oriented location. Use a sequence of position points to describe a line-oriented object (physical location of non-point oriented objects like cables or lines), or area of an object (like a substation or a geographical zone - in this case, have first and last position point with the same values).
sequenceNumber
Zero-relative sequence number of this point within a series of points.
Integer
An integer number. The range is unspecified and not limited.
Primitive
xPosition
X axis position.
yPosition
Y axis position.
zPosition
(if applicable) Z axis position.
Core
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
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StateVariablesProfile
This profile has been built on the basis of the IEC 61970-456 document and adjusted to fit the purpose of the ENTSO-E CGMES.
StateVariablesVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURI
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/StateVariables/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
Core
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
ConductingEquipment
The conducting equipment associated with the status state variable.
Yes
SvStatus
The status state variable associated with this conducting equipment.
SvStatus
No
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
Terminal
The terminal associated with the power flow state variable.
Yes
SvPowerFlow
The power flow state variable associated with the terminal.
SvPowerFlow
No
DC
ACDCConverter
A unit with valves for three phases, together with unit control equipment, essential protective and switching devices, DC storage capacitors, phase reactors and auxiliaries, if any, used for conversion.
idc
Converter DC current, also called Id. Converter state variable, result from power flow.
CurrentFlow
Electrical current with sign convention: positive flow is out of the conducting equipment into the connectivity node. Can be both AC and DC.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
poleLossP
The active power loss at a DC Pole
= idleLoss + switchingLoss*|Idc| + resitiveLoss*Idc^2
For lossless operation Pdc=Pac
For rectifier operation with losses Pdc=Pac-lossP
For inverter operation with losses Pdc=Pac+lossP
Converter state variable used in power flow.
ActivePower
Product of RMS value of the voltage and the RMS value of the in-phase component of the current.
CIMDatatype
value
unit
multiplier
uc
Converter voltage, the voltage at the AC side of the bridge. Converter state variable, result from power flow.
Voltage
Electrical voltage, can be both AC and DC.
CIMDatatype
value
unit
multiplier
udc
Converter voltage at the DC side, also called Ud. Converter state variable, result from power flow.
CsConverter
DC side of the current source converter (CSC).
Description
alpha
Firing angle, typical value between 10 and 18 degrees for a rectifier. CSC state variable, result from power flow.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
multiplier
gamma
Extinction angle. CSC state variable, result from power flow.
DCTopologicalIsland
An electrically connected subset of the network. DC topological islands can change as the current network state changes: e.g. due to
- disconnect switches or breakers change state in a SCADA/EMS
- manual creation, change or deletion of topological nodes in a planning tool.
DCTopologicalIsland
No
DCTopologicalNodes
DCTopologicalNodes
Yes
VsConverter
DC side of the voltage source converter (VSC).
Description
delta
Angle between uf and uc. Converter state variable used in power flow.
uf
Filter bus voltage. Converter state variable, result from power flow.
StateVariables
SvStatus
State variable for status.
Operation
inService
The in service status as a result of topology processing.
Boolean
A type with the value space "true" and "false".
Primitive
SvInjection
The SvInjection is reporting the calculated bus injection minus the sum of the terminal flows. The terminal flow is positive out from the bus (load sign convention) and bus injection has positive flow into the bus. SvInjection may have the remainder after state estimation or slack after power flow calculation.
pInjection
The active power injected into the bus in addition to injections from equipment terminals. Positive sign means injection into the TopologicalNode (bus).
qInjection
The reactive power injected into the bus in addition to injections from equipment terminals. Positive sign means injection into the TopologicalNode (bus).
ReactivePower
Product of RMS value of the voltage and the RMS value of the quadrature component of the current.
CIMDatatype
value
unit
multiplier
SvInjection
The topological node associated with the flow injection state variable.
No
TopologicalNode
The injection flows state variables associated with the topological node.
TopologicalNode
Yes
SvPowerFlow
State variable for power flow. Load convention is used for flow direction. This means flow out from the TopologicalNode into the equipment is positive.
p
The active power flow. Load sign convention is used, i.e. positive sign means flow out from a TopologicalNode (bus) into the conducting equipment.
q
The reactive power flow. Load sign convention is used, i.e. positive sign means flow out from a TopologicalNode (bus) into the conducting equipment.
SvShuntCompensatorSections
State variable for the number of sections in service for a shunt compensator.
sections
The number of sections in service as a continous variable. To get integer value scale with ShuntCompensator.bPerSection.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
ShuntCompensator
The shunt compensator for which the state applies.
Yes
SvShuntCompensatorSections
The state for the number of shunt compensator sections in service.
SvShuntCompensatorSections
No
SvTapStep
State variable for transformer tap step. This class is to be used for taps of LTC (load tap changing) transformers, not fixed tap transformers.
position
The floating point tap position. This is not the tap ratio, but rather the tap step position as defined by the related tap changer model and normally is constrained to be within the range of minimum and maximum tap positions.
TapChanger
The tap changer associated with the tap step state.
Yes
SvTapStep
The tap step state associated with the tap changer.
SvTapStep
No
SvVoltage
State variable for voltage.
angle
The voltage angle of the topological node complex voltage with respect to system reference.
v
The voltage magnitude of the topological node.
SvVoltage
The topological node associated with the voltage state.
No
TopologicalNode
The state voltage associated with the topological node.
TopologicalNode
Yes
Topology
DCTopologicalNode
DC bus.
TopologicalNode
For a detailed substation model a topological node is a set of connectivity nodes that, in the current network state, are connected together through any type of closed switches, including jumpers. Topological nodes change as the current network state changes (i.e., switches, breakers, etc. change state).
For a planning model, switch statuses are not used to form topological nodes. Instead they are manually created or deleted in a model builder tool. Topological nodes maintained this way are also called "busses".
AngleRefTopologicalNode
The angle reference for the island. Normally there is one TopologicalNode that is selected as the angle reference for each island. Other reference schemes exist, so the association is typically optional.
Yes
AngleRefTopologicalIsland
The island for which the node is an angle reference. Normally there is one angle reference node for each island.
AngleRefTopologicalIsland
No
TopologicalNodes
A topological node belongs to a topological island.
Yes
TopologicalIsland
A topological node belongs to a topological island.
TopologicalIsland
No
TopologicalIsland
An electrically connected subset of the network. Topological islands can change as the current network state changes: e.g. due to
- disconnect switches or breakers change state in a SCADA/EMS
- manual creation, change or deletion of topological nodes in a planning tool.
Wires
ShuntCompensator
A shunt capacitor or reactor or switchable bank of shunt capacitors or reactors. A section of a shunt compensator is an individual capacitor or reactor. A negative value for reactivePerSection indicates that the compensator is a reactor. ShuntCompensator is a single terminal device. Ground is implied.
TapChanger
Mechanism for changing transformer winding tap positions.
PK ! ;@ [ cimpyorm/res/schemata/CIM16/SteadyStateHypothesisProfileRDFSAugmented-v2_4_15-16Feb2016.rdf
SteadyStateHypothesisProfile
This profile has been built on the basis of the IEC 61970-456 document and adjusted to fit the purpose of the ENTSO-E CGMES.
SteadyStateHypothesisVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURI
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/SteadyStateHypothesis/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
Core
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
connected
The connected status is related to a bus-branch model and the topological node to terminal relation. True implies the terminal is connected to the related topological node and false implies it is not.
In a bus-branch model, the connected status is used to tell if equipment is disconnected without having to change the connectivity described by the topological node to terminal relation. A valid case is that conducting equipment can be connected in one end and open in the other. In particular for an AC line segment, where the reactive line charging can be significant, this is a relevant case.
Boolean
A type with the value space "true" and "false".
Primitive
ConductingEquipment
The parts of the AC power system that are designed to carry current or that are conductively connected through terminals.
Equipment
The parts of a power system that are physical devices, electronic or mechanical.
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
PowerSystemResource
A power system resource can be an item of equipment such as a switch, an equipment container containing many individual items of equipment such as a substation, or an organisational entity such as sub-control area. Power system resources can have measurements associated.
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
Description
ControlArea
ControlArea
A control area is a grouping of generating units and/or loads and a cutset of tie lines (as terminals) which may be used for a variety of purposes including automatic generation control, powerflow solution area interchange control specification, and input to load forecasting. Note that any number of overlapping control area specifications can be superimposed on the physical model.
Description
netInterchange
The specified positive net interchange into the control area, i.e. positive sign means flow in to the area.
ActivePower
Product of RMS value of the voltage and the RMS value of the in-phase component of the current.
CIMDatatype
value
Float
A floating point number. The range is unspecified and not limited.
Primitive
unit
UnitSymbol
The units defined for usage in the CIM.
VA
Apparent power in volt ampere.
W
Active power in watt.
VAr
Reactive power in volt ampere reactive.
VAh
Apparent energy in volt ampere hours.
Wh
Real energy in what hours.
VArh
Reactive energy in volt ampere reactive hours.
V
Voltage in volt.
ohm
Resistance in ohm.
A
Current in ampere.
F
Capacitance in farad.
H
Inductance in henry.
degC
Relative temperature in degrees Celsius. In the SI unit system the symbol is ºC. Electric charge is measured in coulomb that has the unit symbol C. To distinguish degree Celsius form coulomb the symbol used in the UML is degC. Reason for not using ºC is the special character º is difficult to manage in software.
s
Time in seconds.
min
Time in minutes.
h
Time in hours.
deg
Plane angle in degrees.
rad
Plane angle in radians.
J
Energy in joule.
N
Force in newton.
S
Conductance in siemens.
none
Dimension less quantity, e.g. count, per unit, etc.
Hz
Frequency in hertz.
g
Mass in gram.
Pa
Pressure in pascal (n/m2).
m
Length in meter.
m2
Area in square meters.
m3
Volume in cubic meters.
multiplier
UnitMultiplier
The unit multipliers defined for the CIM.
p
Pico 10**-12.
n
Nano 10**-9.
micro
Micro 10**-6.
m
Milli 10**-3.
c
Centi 10**-2.
d
Deci 10**-1.
k
Kilo 10**3.
M
Mega 10**6.
G
Giga 10**9.
T
Tera 10**12.
none
No multiplier or equivalently multiply by 1.
pTolerance
Active power net interchange tolerance
DC
ACDCConverter
A unit with valves for three phases, together with unit control equipment, essential protective and switching devices, DC storage capacitors, phase reactors and auxiliaries, if any, used for conversion.
p
Active power at the point of common coupling. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for a steady state solution in the case a simplified power flow model is used.
q
Reactive power at the point of common coupling. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for a steady state solution in the case a simplified power flow model is used.
ReactivePower
Product of RMS value of the voltage and the RMS value of the quadrature component of the current.
CIMDatatype
value
unit
multiplier
targetPpcc
Real power injection target in AC grid, at point of common coupling.
targetUdc
Target value for DC voltage magnitude.
Voltage
Electrical voltage, can be both AC and DC.
CIMDatatype
value
unit
multiplier
ACDCConverterDCTerminal
A DC electrical connection point at the AC/DC converter. The AC/DC converter is electrically connected also to the AC side. The AC connection is inherited from the AC conducting equipment in the same way as any other AC equipment. The AC/DC converter DC terminal is separate from generic DC terminal to restrict the connection with the AC side to AC/DC converter and so that no other DC conducting equipment can be connected to the AC side.
Description
CsConverter
DC side of the current source converter (CSC).
Description
operatingMode
Indicates whether the DC pole is operating as an inverter or as a rectifier. CSC control variable used in power flow.
CsOperatingModeKind
Operating mode for HVDC line operating as Current Source Converter.
inverter
Operating as inverter
rectifier
Operating as rectifier.
pPccControl
CsPpccControlKind
Active power control modes for HVDC line operating as Current Source Converter.
activePower
Active power control at AC side.
dcVoltage
DC voltage control.
dcCurrent
DC current control
targetAlpha
Target firing angle. CSC control variable used in power flow.
AngleDegrees
Measurement of angle in degrees.
CIMDatatype
value
unit
multiplier
targetGamma
Target extinction angle. CSC control variable used in power flow.
targetIdc
DC current target value. CSC control variable used in power flow.
CurrentFlow
Electrical current with sign convention: positive flow is out of the conducting equipment into the connectivity node. Can be both AC and DC.
CIMDatatype
value
unit
multiplier
DCBaseTerminal
An electrical connection point at a piece of DC conducting equipment. DC terminals are connected at one physical DC node that may have multiple DC terminals connected. A DC node is similar to an AC connectivity node. The model enforces that DC connections are distinct from AC connections.
DCTerminal
An electrical connection point to generic DC conducting equipment.
Description
VsConverter
DC side of the voltage source converter (VSC).
Description
droop
Droop constant; pu value is obtained as D [kV^2 / MW] x Sb / Ubdc^2.
PU
Per Unit - a positive or negative value referred to a defined base. Values typically range from -10 to +10.
CIMDatatype
value
unit
multiplier
droopCompensation
Compensation (resistance) constant. Used to compensate for voltage drop when controlling voltage at a distant bus.
Resistance
Resistance (real part of impedance).
CIMDatatype
value
unit
multiplier
pPccControl
Kind of control of real power and/or DC voltage.
VsPpccControlKind
Types applicable to the control of real power and/or DC voltage by voltage source converter.
pPcc
Control variable (target) is real power at PCC bus.
udc
Control variable (target) is DC voltage and real power at PCC bus is derived.
pPccAndUdcDroop
Control variables (targets) are both active power at point of common coupling and local DC voltage, with the droop.
pPccAndUdcDroopWithCompensation
Control variables (targets) are both active power at point of common coupling and compensated DC voltage, with the droop; compensation factor is the resistance, as an approximation of the DC voltage of a common (real or virtual) node in the DC network.
pPccAndUdcDroopPilot
Control variables (targets) are both active power at point of common coupling and the pilot DC voltage, with the droop.
qPccControl
VsQpccControlKind
reactivePcc
voltagePcc
powerFactorPcc
qShare
Reactive power sharing factor among parallel converters on Uac control.
PerCent
Percentage on a defined base. For example, specify as 100 to indicate at the defined base.
CIMDatatype
value
Normally 0 - 100 on a defined base
unit
multiplier
targetQpcc
Reactive power injection target in AC grid, at point of common coupling.
targetUpcc
Voltage target in AC grid, at point of common coupling.
Equivalents
EquivalentEquipment
The class represents equivalent objects that are the result of a network reduction. The class is the base for equivalent objects of different types.
EquivalentInjection
This class represents equivalent injections (generation or load). Voltage regulation is allowed only at the point of connection.
Description
regulationStatus
Specifies the default regulation status of the EquivalentInjection. True is regulating. False is not regulating.
regulationTarget
The target voltage for voltage regulation.
p
Equivalent active power injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for steady state solutions.
q
Equivalent reactive power injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for steady state solutions.
Generation
GeneratingUnit
A single or set of synchronous machines for converting mechanical power into alternating-current power. For example, individual machines within a set may be defined for scheduling purposes while a single control signal is derived for the set. In this case there would be a GeneratingUnit for each member of the set and an additional GeneratingUnit corresponding to the set.
Description
normalPF
Generating unit economic participation factor.
Simple_Float
A floating point number. The range is unspecified and not limited.
CIMDatatype
value
HydroGeneratingUnit
A generating unit whose prime mover is a hydraulic turbine (e.g., Francis, Pelton, Kaplan).
Description
NuclearGeneratingUnit
A nuclear generating unit.
Description
SolarGeneratingUnit
A solar thermal generating unit.
Description
ThermalGeneratingUnit
A generating unit whose prime mover could be a steam turbine, combustion turbine, or diesel engine.
Description
WindGeneratingUnit
A wind driven generating unit. May be used to represent a single turbine or an aggregation.
Description
Wires
AsynchronousMachine
A rotating machine whose shaft rotates asynchronously with the electrical field. Also known as an induction machine with no external connection to the rotor windings, e.g squirrel-cage induction machine.
Description
asynchronousMachineType
Indicates the type of Asynchronous Machine (motor or generator).
AsynchronousMachineKind
Kind of Asynchronous Machine.
generator
The Asynchronous Machine is a generator.
motor
The Asynchronous Machine is a motor.
Breaker
A mechanical switching device capable of making, carrying, and breaking currents under normal circuit conditions and also making, carrying for a specified time, and breaking currents under specified abnormal circuit conditions e.g. those of short circuit.
Description
Disconnector
A manually operated or motor operated mechanical switching device used for changing the connections in a circuit, or for isolating a circuit or equipment from a source of power. It is required to open or close circuits when negligible current is broken or made.
Description
EnergyConsumer
Generic user of energy - a point of consumption on the power system model.
Description
p
Active power of the load. Load sign convention is used, i.e. positive sign means flow out from a node.
For voltage dependent loads the value is at rated voltage.
Starting value for a steady state solution.
q
Reactive power of the load. Load sign convention is used, i.e. positive sign means flow out from a node.
For voltage dependent loads the value is at rated voltage.
Starting value for a steady state solution.
EnergySource
A generic equivalent for an energy supplier on a transmission or distribution voltage level.
Description
activePower
High voltage source active injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for steady state solutions.
reactivePower
High voltage source reactive injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for steady state solutions.
ExternalNetworkInjection
This class represents external network and it is used for IEC 60909 calculations.
Description
referencePriority
Priority of unit for use as powerflow voltage phase angle reference bus selection. 0 = don t care (default) 1 = highest priority. 2 is less than 1 and so on.
Integer
An integer number. The range is unspecified and not limited.
Primitive
p
Active power injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for steady state solutions.
q
Reactive power injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for steady state solutions.
GroundDisconnector
A manually operated or motor operated mechanical switching device used for isolating a circuit or equipment from ground.
Operation
ShortCircuit
Description
LoadBreakSwitch
A mechanical switching device capable of making, carrying, and breaking currents under normal operating conditions.
Description
PhaseTapChanger
A transformer phase shifting tap model that controls the phase angle difference across the power transformer and potentially the active power flow through the power transformer. This phase tap model may also impact the voltage magnitude.
PhaseTapChangerAsymmetrical
Describes the tap model for an asymmetrical phase shifting transformer in which the difference voltage vector adds to the primary side voltage. The angle between the primary side voltage and the difference voltage is named the winding connection angle. The phase shift depends on both the difference voltage magnitude and the winding connection angle.
Description
PhaseTapChangerLinear
Describes a tap changer with a linear relation between the tap step and the phase angle difference across the transformer. This is a mathematical model that is an approximation of a real phase tap changer.
The phase angle is computed as stepPhaseShitfIncrement times the tap position.
The secondary side voltage magnitude is the same as at the primary side.
Description
PhaseTapChangerNonLinear
The non-linear phase tap changer describes the non-linear behavior of a phase tap changer. This is a base class for the symmetrical and asymmetrical phase tap changer models. The details of these models can be found in the IEC 61970-301 document.
PhaseTapChangerSymmetrical
Describes a symmetrical phase shifting transformer tap model in which the secondary side voltage magnitude is the same as at the primary side. The difference voltage magnitude is the base in an equal-sided triangle where the sides corresponds to the primary and secondary voltages. The phase angle difference corresponds to the top angle and can be expressed as twice the arctangent of half the total difference voltage.
Description
PhaseTapChangerTabular
Description
ProtectedSwitch
A ProtectedSwitch is a switching device that can be operated by ProtectionEquipment.
RatioTapChanger
A tap changer that changes the voltage ratio impacting the voltage magnitude but not the phase angle across the transformer.
Description
RegulatingCondEq
A type of conducting equipment that can regulate a quantity (i.e. voltage or flow) at a specific point in the network.
controlEnabled
Specifies the regulation status of the equipment. True is regulating, false is not regulating.
RotatingMachine
A rotating machine which may be used as a generator or motor.
p
Active power injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for a steady state solution.
q
Reactive power injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for a steady state solution.
StaticVarCompensator
A facility for providing variable and controllable shunt reactive power. The SVC typically consists of a stepdown transformer, filter, thyristor-controlled reactor, and thyristor-switched capacitor arms.
The SVC may operate in fixed MVar output mode or in voltage control mode. When in voltage control mode, the output of the SVC will be proportional to the deviation of voltage at the controlled bus from the voltage setpoint. The SVC characteristic slope defines the proportion. If the voltage at the controlled bus is equal to the voltage setpoint, the SVC MVar output is zero.
Description
q
Reactive power injection. Load sign convention is used, i.e. positive sign means flow out from a node.
Starting value for a steady state solution.
Switch
A generic device designed to close, or open, or both, one or more electric circuits. All switches are two terminal devices including grounding switches.
Description
open
The attribute tells if the switch is considered open when used as input to topology processing.
SynchronousMachine
An electromechanical device that operates with shaft rotating synchronously with the network. It is a single machine operating either as a generator or synchronous condenser or pump.
Description
operatingMode
Current mode of operation.
SynchronousMachineOperatingMode
Synchronous machine operating mode.
generator
condenser
motor
referencePriority
Priority of unit for use as powerflow voltage phase angle reference bus selection. 0 = don t care (default) 1 = highest priority. 2 is less than 1 and so on.
TapChangerControl
Describes behavior specific to tap changers, e.g. how the voltage at the end of a line varies with the load level and compensation of the voltage drop by tap adjustment.
Description
LinearShuntCompensator
A linear shunt compensator has banks or sections with equal admittance values.
Description
NonlinearShuntCompensator
A non linear shunt compensator has bank or section admittance values that differs.
Description
RegulatingControl
Specifies a set of equipment that works together to control a power system quantity such as voltage or flow.
Remote bus voltage control is possible by specifying the controlled terminal located at some place remote from the controlling equipment.
In case multiple equipment, possibly of different types, control same terminal there must be only one RegulatingControl at that terminal. The most specific subtype of RegulatingControl shall be used in case such equipment participate in the control, e.g. TapChangerControl for tap changers.
For flow control load sign convention is used, i.e. positive sign means flow out from a TopologicalNode (bus) into the conducting equipment.
Description
discrete
The regulation is performed in a discrete mode. This applies to equipment with discrete controls, e.g. tap changers and shunt compensators.
enabled
The flag tells if regulation is enabled.
targetDeadband
This is a deadband used with discrete control to avoid excessive update of controls like tap changers and shunt compensator banks while regulating.
The units of those appropriate for the mode.
targetValue
The target value specified for case input. This value can be used for the target value without the use of schedules. The value has the units appropriate to the mode attribute.
targetValueUnitMultiplier
Specify the multiplier for used for the targetValue.
ShuntCompensator
A shunt capacitor or reactor or switchable bank of shunt capacitors or reactors. A section of a shunt compensator is an individual capacitor or reactor. A negative value for reactivePerSection indicates that the compensator is a reactor. ShuntCompensator is a single terminal device. Ground is implied.
sections
Shunt compensator sections in use.
Starting value for steady state solution. Non integer values are allowed to support continuous variables. The reasons for continuous value are to support study cases where no discrete shunt compensators has yet been designed, a solutions where a narrow voltage band force the sections to oscillate or accommodate for a continuous solution as input.
TapChanger
Mechanism for changing transformer winding tap positions.
controlEnabled
Specifies the regulation status of the equipment. True is regulating, false is not regulating.
step
Tap changer position.
Starting step for a steady state solution. Non integer values are allowed to support continuous tap variables. The reasons for continuous value are to support study cases where no discrete tap changers has yet been designed, a solutions where a narrow voltage band force the tap step to oscillate or accommodate for a continuous solution as input.
The attribute shall be equal or greater than lowStep and equal or less than highStep.
LoadModel
ConformLoad
ConformLoad represent loads that follow a daily load change pattern where the pattern can be used to scale the load with a system load.
Description
NonConformLoad
NonConformLoad represent loads that do not follow a daily load change pattern and changes are not correlated with the daily load change pattern.
Description
StationSupply
Station supply with load derived from the station output.
Operation
Description
PK ! x x V cimpyorm/res/schemata/CIM16/TopologyBoundaryProfileRDFSAugmented-v2_4_15-16Feb2016.rdf
TopologyBoundaryProfile
This profile has been built on the basis of the IEC 61970-456 document and adjusted to fit the purpose of the ENTSO-E boundary profile.
TopologyBoundaryVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURI
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/TopologyBoundary/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
Core
BaseVoltage
Defines a system base voltage which is referenced.
BaseVoltage
The base voltage of the topologocial node.
Yes
TopologicalNode
The topological nodes at the base voltage.
TopologicalNode
No
ConnectivityNode
Connectivity nodes are points where terminals of AC conducting equipment are connected together with zero impedance.
Operation
Description
TopologicalNode
The topological node to which this connectivity node is assigned. May depend on the current state of switches in the network.
Yes
ConnectivityNodes
The connectivity nodes combine together to form this topological node. May depend on the current state of switches in the network.
ConnectivityNodes
No
ConnectivityNodeContainer
A base class for all objects that may contain connectivity nodes or topological nodes.
ConnectivityNodeContainer
The connectivity node container to which the toplogical node belongs.
Yes
TopologicalNode
The topological nodes which belong to this connectivity node container.
TopologicalNode
No
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
energyIdentCodeEic
Entsoe
The attribute is used for an exchange of the EIC code (Energy identification Code). The length of the string is 16 characters as defined by the EIC code.
References:
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
shortName
Entsoe
The attribute is used for an exchange of a human readable short name with length of the string 12 characters maximum.
Topology
TopologicalNode
For a detailed substation model a topological node is a set of connectivity nodes that, in the current network state, are connected together through any type of closed switches, including jumpers. Topological nodes change as the current network state changes (i.e., switches, breakers, etc. change state).
For a planning model, switch statuses are not used to form topological nodes. Instead they are manually created or deleted in a model builder tool. Topological nodes maintained this way are also called "busses".
boundaryPoint
Entsoe
Identifies if a node is a BoundaryPoint. If boundaryPoint=true the ConnectivityNode or the TopologicalNode represents a BoundaryPoint.
Boolean
A type with the value space "true" and "false".
Primitive
fromEndIsoCode
Entsoe
The attribute is used for an exchange of the ISO code of the region to which the “From” side of the Boundary point belongs to or it is connected to.
The ISO code is two characters country code as defined by ISO 3166 (
http://www.iso.org/iso/country_codes
). The length of the string is 2 characters maximum.
The attribute is a required for the Boundary Model Authority Set where this attribute is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
fromEndName
Entsoe
The attribute is used for an exchange of a human readable name with length of the string 32 characters maximum. The attribute covers two cases:
- if the Boundary point is placed on a tie-line the attribute is used for exchange of the geographical name of the substation to which the “From” side of the tie-line is connected to.
- if the Boundary point is placed in a substation the attribute is used for exchange of the name of the element (e.g. PowerTransformer, ACLineSegment, Switch, etc) to which the “From” side of the Boundary point is connected to.
The attribute is required for the Boundary Model Authority Set where it is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
fromEndNameTso
Entsoe
The attribute is used for an exchange of the name of the TSO to which the “From” side of the Boundary point belongs to or it is connected to. The length of the string is 32 characters maximum.
The attribute is required for the Boundary Model Authority Set where it is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
toEndIsoCode
Entsoe
The attribute is used for an exchange of the ISO code of the region to which the “To” side of the Boundary point belongs to or it is connected to.
The ISO code is two characters country code as defined by ISO 3166 (
http://www.iso.org/iso/country_codes
). The length of the string is 2 characters maximum.
The attribute is a required for the Boundary Model Authority Set where this attribute is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
toEndName
Entsoe
The attribute is used for an exchange of a human readable name with length of the string 32 characters maximum. The attribute covers two cases:
- if the Boundary point is placed on a tie-line the attribute is used for exchange of the geographical name of the substation to which the “To” side of the tie-line is connected to.
- if the Boundary point is placed in a substation the attribute is used for exchange of the name of the element (e.g. PowerTransformer, ACLineSegment, Switch, etc) to which the “To” side of the Boundary point is connected to.
The attribute is required for the Boundary Model Authority Set where it is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
toEndNameTso
Entsoe
The attribute is used for an exchange of the name of the TSO to which the “To” side of the Boundary point belongs to or it is connected to. The length of the string is 32 characters maximum.
The attribute is required for the Boundary Model Authority Set where it is used only for the TopologicalNode in the Boundary Topology profile and ConnectivityNode in the Boundary Equipment profile.
PK ! f-% % N cimpyorm/res/schemata/CIM16/TopologyProfileRDFSAugmented-v2_4_15-16Feb2016.rdf
TopologyProfile
This profile has been built on the basis of the IEC 61970-456 document and adjusted to fit the purpose of the ENTSO-E CGMES.
TopologyVersion
Version details.
Entsoe
baseUML
Base UML provided by CIM model manager.
String
A string consisting of a sequence of characters. The character encoding is UTF-8. The string length is unspecified and unlimited.
Primitive
baseURI
Profile URI used in the Model Exchange header and defined in IEC standards. It uniquely identifies the Profile and its version. It is given for information only and to identify the closest IEC profile to which this CGMES profile is based on.
date
Profile creation date
Form is YYYY-MM-DD for example for January 5, 2009 it is 2009-01-05.
Date
Date as "yyyy-mm-dd", which conforms with ISO 8601. UTC time zone is specified as "yyyy-mm-ddZ". A local timezone relative UTC is specified as "yyyy-mm-dd(+/-)hh:mm".
Primitive
differenceModelURI
Difference model URI defined by IEC 61970-552.
entsoeUML
UML provided by ENTSO-E.
entsoeURI
Profile URI defined by ENTSO-E and used in the Model Exchange header. It uniquely identifies the Profile and its version. The last two elements in the URI (http://entsoe.eu/CIM/Topology/yy/zzz) indicate major and minor versions where:
- yy - indicates a major version;
- zzz - indicates a minor version.
modelDescriptionURI
Model Description URI defined by IEC 61970-552.
namespaceRDF
RDF namespace.
namespaceUML
CIM UML namespace.
shortName
The short name of the profile used in profile documentation.
Core
Contains the core PowerSystemResource and ConductingEquipment entities
ACDCTerminal
An electrical connection point (AC or DC) to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
BaseVoltage
Defines a system base voltage which is referenced.
BaseVoltage
The base voltage of the topologocial node.
Yes
TopologicalNode
The topological nodes at the base voltage.
TopologicalNode
No
ConnectivityNode
Connectivity nodes are points where terminals of AC conducting equipment are connected together with zero impedance.
Operation
Description
ConnectivityNodes
The topological node to which this connectivity node is assigned. May depend on the current state of switches in the network.
No
TopologicalNode
The connectivity nodes combine together to form this topological node. May depend on the current state of switches in the network.
TopologicalNode
Yes
ConnectivityNodeContainer
A base class for all objects that may contain connectivity nodes or topological nodes.
ConnectivityNodeContainer
The connectivity node container to which the toplogical node belongs.
Yes
TopologicalNode
The topological nodes which belong to this connectivity node container.
TopologicalNode
No
ReportingGroup
A reporting group is used for various ad-hoc groupings used for reporting.
TopologicalNode
The reporting group to which the topological node belongs.
No
ReportingGroup
The topological nodes that belong to the reporting group.
ReportingGroup
Yes
IdentifiedObject
This is a root class to provide common identification for all classes needing identification and naming attributes.
description
The description is a free human readable text describing or naming the object. It may be non unique and may not correlate to a naming hierarchy.
energyIdentCodeEic
Entsoe
The attribute is used for an exchange of the EIC code (Energy identification Code). The length of the string is 16 characters as defined by the EIC code.
References:
mRID
Master resource identifier issued by a model authority. The mRID is globally unique within an exchange context. Global uniqueness is easily achieved by using a UUID, as specified in RFC 4122, for the mRID. The use of UUID is strongly recommended.
For CIMXML data files in RDF syntax conforming to IEC 61970-552 Edition 1, the mRID is mapped to rdf:ID or rdf:about attributes that identify CIM object elements.
name
The name is any free human readable and possibly non unique text naming the object.
shortName
Entsoe
The attribute is used for an exchange of a human readable short name with length of the string 12 characters maximum.
Terminal
An AC electrical connection point to a piece of conducting equipment. Terminals are connected at physical connection points called connectivity nodes.
Description
Terminal
The topological node associated with the terminal. This can be used as an alternative to the connectivity node path to topological node, thus making it unneccesary to model connectivity nodes in some cases. Note that the if connectivity nodes are in the model, this association would probably not be used as an input specification.
No
TopologicalNode
The terminals associated with the topological node. This can be used as an alternative to the connectivity node path to terminal, thus making it unneccesary to model connectivity nodes in some cases. Note that if connectivity nodes are in the model, this association would probably not be used as an input specification.
TopologicalNode
Yes
DC
ACDCConverterDCTerminal
A DC electrical connection point at the AC/DC converter. The AC/DC converter is electrically connected also to the AC side. The AC connection is inherited from the AC conducting equipment in the same way as any other AC equipment. The AC/DC converter DC terminal is separate from generic DC terminal to restrict the connection with the AC side to AC/DC converter and so that no other DC conducting equipment can be connected to the AC side.
Description
DCBaseTerminal
An electrical connection point at a piece of DC conducting equipment. DC terminals are connected at one physical DC node that may have multiple DC terminals connected. A DC node is similar to an AC connectivity node. The model enforces that DC connections are distinct from AC connections.
DCTerminals
See association end Terminal.TopologicalNode.
No
DCTopologicalNode
See association end TopologicalNode.Terminal.
DCTopologicalNode
Yes
DCEquipmentContainer
A modeling construct to provide a root class for containment of DC as well as AC equipment. The class differ from the EquipmentContaner for AC in that it may also contain DCNodes. Hence it can contain both AC and DC equipment.
DCEquipmentContainer
Yes
DCTopologicalNode
DCTopologicalNode
No
DCNode
DC nodes are points where terminals of DC conducting equipment are connected together with zero impedance.
Description
DCNodes
See association end ConnectivityNode.TopologicalNode.
No
DCTopologicalNode
See association end TopologicalNode.ConnectivityNodes.
DCTopologicalNode
Yes
DCTerminal
An electrical connection point to generic DC conducting equipment.
Description
DCTopologicalNode
DC bus.
Topology
TopologicalNode
For a detailed substation model a topological node is a set of connectivity nodes that, in the current network state, are connected together through any type of closed switches, including jumpers. Topological nodes change as the current network state changes (i.e., switches, breakers, etc. change state).
For a planning model, switch statuses are not used to form topological nodes. Instead they are manually created or deleted in a model builder tool. Topological nodes maintained this way are also called "busses".
PK ! K<+ + cimpyorm-0.4.6.dist-info/LICENSEBSD 3-Clause License
Copyright (c) 2018, Thomas Offergeld, Institute for High Voltage Technology, RWTH Aachen University
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