This part of IEC 61970 belongs to the IEC 61970-450 to IEC 61970-499 series that, taken as a
whole, defines at an abstract level the content and exchange mechanisms used for data
transmitted between power system analyses applications, control centres and/or control centre
components.
The purpose of this document is to rigorously define the subset of classes, class attributes, and
roles from the CIM necessary to describe the result of state estimation, power flow and other
similar applications that produce a steady-state solution of a power network, under a set of use
cases which are included informatively in this document.
This document is intended for two distinct audiences, data producers and data recipients, and
can be read from those two perspectives. From the standpoint of model export software used
by a data producer, the document defines how a producer may describe an instance of a
network case in order to make it available to some other program. From the standpoint of a
consumer, the document defines what that importing software must be able to interpret in order
to consume power flow cases.
There are many different use cases for which use of this document is expected and they differ
in the way that the document will be applied in each case. Implementers are expected to
consider what use cases they wish to cover in order to know the extent of different options they
must cover. As an example, the profiles defined in this document will be used in some cases to
exchange starting conditions rather than solved conditions, so if this is an important use case,
it means that a consumer application needs to be able to handle an unsolved state as well as
one which has met some solution criteria

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IEC 61968-100:2022 defines how messages may be exchanged between cooperating systems in order to facilitate the transfer of application-specific data. Such application-specific data include but are not limited to the message payloads defined in IEC 61968 (Parts 3 to 9 and Part 13), IEC 61970 and IEC 62325.
This IEC 61968-100:2022 edition cancels and replaces the IEC 61968-100:2013 edition published in 2013. This edition constitutes a technical revision.
a) This edition includes the following significant technical changes with respect to the previous edition: IEC 61968-100:2022 has been refined to remove ambiguities and redundancies. Informative and normative clauses are marked as such and, in the latter case, appropriate verbal forms of language are used;
b) The messages defined by IEC 61968-100:2022 are in general not backwards compatible with those of IEC 61968-100:2013. Annex I lists the significant technical changes introduced since the publication of IEC 61968-100:2013 and provides appropriate suggestions for migrating to IEC 61968-100:2022.

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IEC TR 61850-10-3:2022(E), which is a technical report, is applicable to testing of applications within substations. It is intended to give practical guidelines to perform the stages of quality assurance defined in IEC 61850-4:2011. However, while the quality assurance in that document begins with the IED manufacturer development stage and focuses on the role of the system integrator this document focuses on end-user requirement fulfilment.
The report may be useful to users applying IEC 61850 to other domains, however testing of IEC 61850 systems outside the substation domain is not within the scope of this document.
This document describes:
• A methodical approach to the verification and validation of a substation solution
• The use of IEC 61850 resources for testing in Edition 2.1
• Recommended testing practices for different use cases
• Definition of the process for testing of IEC 61850 based devices and systems using communications instead of hard wired system interfaces (ex. GOOSE and SV instead of hardwired interfaces)
• Use cases related to protection and control functions verification and testing
This document does not cover the conformance testing of devices according to IEC 61850-10 or methodologies for testing of abstract device independent functions.

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This part of IEC 61850 defines the IEC 61850 information models to be used in the exchange
of information with distributed energy resources (DER) and Distribution Automation (DA)
systems. DERs include distribution-connected generation systems, energy storage systems,
and controllable loads, as well as facility DER management systems, including aggregated
DER, such as plant control systems, facility DER energy management systems (EMS), building
EMS, campus EMS, community EMS, microgrid EMS, etc. DA equipment includes equipment
used to manage distribution circuits, including automated switches, fault indicators, capacitor
banks, voltage regulators, and other power management devices.
The IEC 61850 DER information model standard utilizes existing IEC 61850-7-4 logical nodes
where possible, while defining DER and DA specific logical nodes to provide the necessary data
objects for DER and DA functions, including for the DER interconnection grid codes specified
by various countries and regions.
Although this document explicitly addresses distribution-connected resources, most of the
resource capabilities, operational functions, and architectures are also applicable to
transmission-connected resources

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This document is one of the IEC 61970-450 to 499 series that, taken as a whole, defines at an abstract level the content and exchange mechanisms used for data transmitted between control centres and/or control centre components, such as power systems applications.
The purpose of this document is to define the subset of classes, class attributes, and roles from the CIM necessary to execute state estimation and power flow applications. The North American Electric Reliability Council (NERC) Data Exchange Working Group (DEWG) Common Power System Modelling group (CPSM) produced the original data requirements, which are shown in Annex E. These requirements are based on prior industry practices for exchanging power system model data for use primarily in planning studies. However, the list of required data has been extended starting with the first edition of this standard to facilitate a model exchange that includes parameters common to breaker-oriented applications. Where necessary this document establishes conventions, shown in Clause 6, with which an XML data file must comply in order to be considered valid for exchange of models.
This document is intended for two distinct audiences, data producers and data recipients, and may be read from two perspectives.
From the standpoint of model export software used by a data producer, the document describes a minimum subset of CIM classes, attributes, and associations which must be present in an XML formatted data file for model exchange. This standard does not dictate how the network is modelled, however. It only dictates what classes, attributes, and associations are to be used to describe the source model as it exists.

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This document specifies data exchange and communications for meters in a generic way.
This document establishes a protocol specification for the Application Layer for meters and establishes several protocols for meter communications which can be applied depending on the application being fulfilled.
This document also specifies the overall structure of the OBject Identification System (OBIS) and the mapping of all commonly used data items in metering equipment to their identification codes.”
NOTE   Electricity meters are not covered by this document, as the standardization of remote readout of electricity meters is a task for CENELEC/IEC.

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This document specifies the minimum requirements for secure remote services (e. g. via IP connections) to the following systems:
a) fire safety systems including, but not limited to, fire detection and fire alarm systems, fixed firefighting systems, smoke and heat control
systems,
b) security systems including, but not limited to, intruder and hold-up alarm systems, electronic access control systems, external perimeter security systems and video surveillance systems,
c) social alarm systems,
d) a combination of such systems
The scope doesn´t cover:
a) the alarm transmission infrastructure,
b) the use of remote access performed by end-users

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IEC 61970-452:2021 defines the subset of classes, class attributes, and associations from the CIM necessary to execute state estimation and power flow applications between control centres and/or control centre components, such as power systems applications.
The North American Electric Reliability Council (NERC) Data Exchange Working Group (DEWG) Common Power System Modelling group (CPSM) produced the original data requirements, which are shown in Annex F. These requirements are based on prior industry practices for exchanging power system model data for use primarily in planning studies. However, the list of required data has been extended starting with the first edition of this standard to facilitate a model exchange that includes parameters common to breaker-oriented applications. Where necessary this document establishes conventions, shown in Clause 6, with which an XML data file must comply in order to be considered valid for exchange of models.
The data exchange use cases which this standard is meant to support are described in Annex A. The idea of a modelling authority as the source responsible for the modeling of a given region is described in Annex B. The concept of a boundary between regions is explained in Annex C. Annex D explains the processing of multiple profiles such as the three profiles described in this standard. The use of different curve styles to define ReactiveCapabilityCurve-s is explained in Annex E.
This document is intended for two distinct audiences, data producers and data recipients, and may be read from two perspectives.
From the standpoint of model export software used by a data producer, this document describes a minimum subset of CIM classes, attributes, and associations which must be present in an XML formatted data file for model exchange. This document does not dictate how the network is modelled, however. It only dictates what classes, attributes, and associations are to be used to describe the source model as it exists.
This fourth edition cancels and replaces the third edition published in 2017. This edition constitutes a technical revision. It is based on the IEC 61970 UML version ‘IEC61970CIM17v40’, dated 2020-08-24.
This edition includes the following significant technical changes with respect to the previous edition:
a) The classes PowerElectronicsConnection, PowerElectronicsUnit and PowerElectronicsWindUnit are added to the Core Equipment profile.

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Per the IEC 61968 Interface Reference Model, the Network Operations function defined in this part of IEC 61968 provides utilities the means to supervise main substation topology (breaker and switch state), feeder topology and control equipment status through SCADA, AMI and other data sources. It also provides the means for handling network connectivity and loading conditions. Finally, it makes it possible for utilities to locate customer telephone complaints and coordinate activities of field crews with respect to planned and unplanned outages.
IEC 61968-3 specifies the information content of a set of message payloads that can be used to support many of the business functions related to network operations. Typical uses of the message payloads defined in IEC 61968-3 include data acquisition by external systems, fault isolation, fault restoration, trouble management and coordination of the real-time state of the network.
The scope diagram shown in [Figure 1] illustrates the possibility of implementing IEC 61968-3 functionality 51 as either a single integrated advanced distribution management system or as a set of separate functions - OMS, DMS and SCADA. Utilities may chose to buy these systems from different vendors and integrate them using the IEC 61968-3 messages. Alternatively, a single vendor could provide two or all of these components as a single integrated system. In the case of more than one system being provided by the same vendor, the vendor may chose to use either extensions of the IEC 61968- messages or a proprietary integration mechanism to provide enhanced functionality over and above what is required/supported by the IEC 61968-3 specification. While this is a possible implementation, clause 4.3 defines the scope in terms of business functions that are implemented in common vendor offerings.
Annexes in this standard document integration scenarios or use cases, which are informative examples showing typical ways of using the message payloads defined in this document as well as message payloads to be defined in other parts of the IEC 61968 series.

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This part of IEC 62488 applies to power line carrier terminals and networks used to transmit information over power networks including extra high, high and medium voltage (EHV/HV/MV) power lines using both digital and optionally analogue modulation systems in a frequency range between 16 kHz and 1 MHz (see also IEC 62488-1). In many countries, power line carrier (PLC) channels represent a significant part of the utilityowned telecommunication system. A circuit normally routed via a PLC channel can also be routed via a channel using a different transmission medium such as point to point radio, optical fibre or open wire circuit. It is therefore important that the input and output interfaces that are used between terminals in the communication system are standardised. The issues requiring consideration of DPLC and/or APLC devices as parts of a telecommunication network can be found in IEC 62488-1. Figure 1 shows the correspondence between the elements needed to implement PLC systems and the related International Standards.

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This part of IEC 62325 specifies a UML package for the electricity balancing business process
and its associated document contextual models, assembly models and XML schemas for use
within the European style electricity markets.
This part of IEC 62325 is based on the European style market contextual model
(IEC 62325-351). The business process covered by this part of IEC 62325 is described in
Clause 5.
The relevant aggregate core components (ACCs) defined in IEC 62325-351 have been
contextualised into aggregated business information entities (ABIEs) to satisfy the requirements
of the European style market publication business process.

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IEC 61970-600-2:2021 defines the profiles included in the Common Grid Model Exchange Standard (CGMES) that are based on IEC 61970-450-series and IEC 61968-13 profiles. This document refers to the IEC 61970-450-series and IEC 61968-13 profiles only in cases where they are identical. If the referenced profile is not yet published, this document includes the profile definition and related constraints’ definitions. In the case where a CGMES profile makes restriction on the referenced profile, the restriction is defined in this document.
The equipment boundary profile (EQBD) is the only profile that is not part of IEC 61970-450-series and IEC 61968-13 profiles. This profile is deprecated as modifications have been made to align between EQBP and the equipment profile (EQ). Although the updated EQBD is addressing the requirement that boundary also can be located inside a substation, which will be the case for many Distribution System Operators (DSOs), additional information would need to be exchanged. For instance, system integrity protection schemes, that can be shared by multiple utility would require another way of boundary handling. In this document EQBD is included in CGMES only to create better backwards compatibility with previous version of the CGMES.
The machine-readable documentation that supports model driven development of the profiles defined in this part are generated as Resource Description Framework Schema (RDFS) according to IEC 61970-501:2006 (with some extension) and IEC 61970-501:ED2 when published.

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IEC 61970-600-1:2021 covers the definition of Common Grid Model Exchange Standard (CGMES), defines the main rules and application’s requirements to meet business requirements for assembled and merged model to fit relevant business services. This document does not define the business requirements, business processes nor how applications are implemented. This document defines how relevant Common Information Model (CIM) standards work together so that specific business requirements can be resolved.
It also includes extensions to the Common Information Model (CIM). The current extensions are defined in IEC 61970-301:2020 and will be covered in its future Amendment 1, but additional extensions can be defined in other standards in the IEC 61970-600-series. The extensions can be used to define additional profiles or to expand IEC 61970-450-series or IEC 61968-13 profiles. However, primary CGMES includes additional constraints on existing profiles and validation of assembled and merged models that is based on existing profiles. This can be done by making optional attributes and associations mandatory (required).
In addition, this document includes the specification of the serialisation that must be supported by referring to an existing standard defined in IEC 61970-550-series, e.g. IEC 61970-552, and making relevant constraints related to it.
The goal is to achieve interoperability between applications using CGMES in a high-performance environment with combined minimum effort so that relevant business processes are satisfied.
This first edition cancels and replaces IEC TS 61970-600-1 published in 2017. This edition constitutes a technical revision.

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IEC 61076-2-010:2021 specifies circular connectors with a push-pull locking mechanism of a size derived from, and thus being compatible with M12 screw-locking connectors (free connectors with screw-locking according to IEC 61076-2-101, IEC 61076-2-109, IEC 61076-2-111 or IEC 61076-2-113 are compatible with push‑pull fixed interfaces according to this document) and with mating interfaces according to IEC 61076-2-101, IEC 61076-2-109, IEC 61076-2-111 (except codings E in general and coding F for inner push-pull) or IEC 61076-2-113.
A fixed connector with push-pull locking according to this document is intermateable with a correspondingly coded free connector with M12 screw-locking according to any of the above mentioned standards.
M12 is the dimension of the thread of the screw-locking mechanism of circular connectors with M12 screw-locking.
IEC 61076-2-012 defines another inner push-pull for fixed female connectors which is however not compatible to the inner push-pull defined in this document. Annex C shows the different styles of female free connectors to extend male free connectors.
This document covers both:
a) power connectors with current ratings up to 16 A and voltage ratings up to 630 V, typically used for power supply and power applications in industrial premises, and
b) connectors for data and signal transmission with frequencies up to 500 MHz.
These connectors consist of both, fixed and free connectors, either rewirable or non-rewirable, with M12 push-pull locking as explained above. Male connectors have round contacts from Ø 0,6 mm up to Ø 1,5 mm. In addition, the push-pull mechanisms consist of 2 different push-pull designs:
c) An outer push-pull for male and female fixed connector, where the locking groove is placed onto the outer cylindric surface of the housing. The outer push-pull for female fixed connectors is made for 2 different types of male connectors. It has locking means for both types on its outer surface.
For design and dimensions see 5.3.2 and 5.3.3.
d) An inner push-pull for female fixed connectors and for male free connectors, where the locking means are placed onto the inner cylindric surface of the housing.
For design and dimensions see 5.3.4.
The different codings provided by IEC 61076-2 series detail specifications mentioned within this document prevent the mating of accordingly coded male or female connectors to any other similarly sized interfaces, covered by other standards and the cross-mating between the different codings provided by any other IEC 61076-2 series detail specification mentioned within this document.

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This part of IEC 61968 specifies profiles that can be used to exchange Network Models in a
Utility or between a Utility and external applications to the utility. This document provides a list
of profiles which allow to model balanced and unbalanced distribution networks in order to
conduct network analysis (Power flow calculation). Therefore, it leverages already existing
profiles (IEC 61970-45x based on IEC 61970-301 (CIM base) or profiles based on
IEC 6196811
CIM extension for Distribution). This document reuses some profiles without any
change, or eventually extends them or restricts them. Moreover, it proposes other profiles to
reflect Distribution needs.
Use of CIM in Distribution is not a new topic. Several documents can be of interest
[13][17][18][19][20]. This document includes informative parts, as CIM model extensions, which
could be integrated in future versions of the IEC CIM Model. These extensions have been used
by some utilities for utility internal information exchange use cases and to support information
exchanges between different market participants like Transmisstion System Operators (TSO),
Distributed System Operators (DSO), Distributed Network Operators (DNO) and Significant Grid
Users (SGU) including generators and industry (see Annex J for example).

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IEC 61968-3:2021 provides utilities with the means to supervise main substation topology (breaker and switch state), feeder topology and control equipment status through SCADA, AMI and other data sources. It also provides the means for handling network connectivity and loading conditions. Finally, it makes it possible for utilities to locate customer telephone complaints and coordinate activities of field crews with respect to planned and unplanned outages.
IEC 61968-3 specifies the information content of a set of message payloads that can be used to support many of the business functions related to network operations. Typical uses of the message payloads defined in IEC 61968-3 include data acquisition by external systems, fault isolation, fault restoration, trouble management and coordination of the real-time state of the network.
The scope illustrates the possibility of implementing IEC 61968-3 functionality as either a single integrated advanced distribution management system or as a set of separate functions – OMS, DMS and SCADA. Utilities may choose to buy these systems from different vendors and integrate them using the IEC 61968-3 messages. Alternatively, a single vendor could provide two or all of these components as a single integrated system. In the case of more than one system being provided by the same vendor, the vendor may choose to use either extensions of the IEC 61968 messages or a proprietary integration mechanism to provide enhanced functionality over and above what is required/supported by the IEC 61968-3 specification. While this is a possible implementation, Subclause 4.3 defines the scope in terms of business functions that are implemented in common vendor offerings.
Annexes in this document detail integration scenarios or use cases, which are informative examples showing typical ways of using the message payloads defined in this document as well as message payloads to be defined in other parts of the IEC 61968 series
This third edition cancels and replaces the second edition published in 2017. This edition constitutes a technical revision.
This edition includes the following significant technical changes with respect to the previous edition:
a) major rework of Switch Order related profiles and Outage related profiles;
b) documented profiles in more detail as a result of the analysis of end-to-end use cases;
c) separated Measurement and Control profile into two profiles: PSRMeasurements and PSRControls;
d) replaced Temporary Network Change profile with SwitchingEvents profile;
e) added MeasurementAction, ControlAction, GenericAction and VerificationAction to SwitchingPlans profile. Added examples;
f) added SwitchingActions profile to support the coordination of SwitchingPlan execution between control room and the field crew;
g) added ClampAction to SwitchingPlan, SwitchingAction and SwitchingEvent profiles, to allow clamps to be placed and removed independently of jumpers;
h) separated OutagesAndFaults profile into UnplannedOutages, PlannedOutages, EquipmentFaults, LineFaults;
i) added list of energized and de-energized UsagePoints to the UnplannedOutages profile;
j) added PlannedOutages profile;
k) added PlannedOutageNotifications profile;
l) added SwitchingPlanRequest profile to replace OutageSchedules profile;
m) expanded TroubleOrders profile to include UnplannedOutages and TroubleTickets and to allow crews to be scheduled to individual tasks within the TroubleOrder;
n) expanded use cases and sequence diagrams;
o) sequence diagrams updated to use IEC 61968-100 message patterns;
p) use cases in IEC 62559-2 use case template;
q) added example XML for profiles;
r) replaced xsd in Annex with tables to document the profiles in a serialisation-independent form;
s) clarified FLISR use case to include interactions between DSO and TSO per review comments from Edition 2.
t) removed OperationalTags since it is now part of the TagAction in the SwitchingEvents payload

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IEC 62488-3:2021 applies to power line carrier terminals and networks used to transmit information over power networks including extra high, high and medium voltage (EHV/HV/MV) power lines using both digital and optionally analogue modulation systems in a frequency range between 16 kHz and 1 MHz (see also IEC 62488-1).
In many countries, power line carrier (PLC) channels represent a significant part of the utility-owned telecommunication system. A circuit normally routed via a PLC channel can also be routed via a channel using a different transmission medium such as point to point radio, optical fibre or open wire circuit.
It is therefore important that the input and output interfaces that are used between terminals in the communication system are standardised.
The issues requiring consideration of DPLC and/or APLC devices as parts of a telecommunication network can be found in IEC 62488-1.
The scope of this document also includes the description of I/O interfaces and test set-ups that are necessary to qualify characteristics of DPLC or ADPLC terminal at link level.

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IEC TR 61850-7-5:2021, which is a technical report, establishes modelling concepts that help the user to understand how to apply the models defined in IEC 61850-7-4 and IEC 61850-7-3 to implement practical applications.
This document provides the basic concepts that are valid for all application domains using IEC 61850. Domain specific concepts are defined in other technical reports as in the document range of IEC 61850-7-5xx; as an example, IEC 61850-7-500 describes modelling concepts for functions related to substation automation.
On one side the number of potential topics for cross-domain modelling may be very high but on the other side it may be limited by domain specific restrictions often created by the historical evolution of IEC 61850 in the domains.
The first topic selected is the common control of power utility primary objects by means of the power utility automation systems based mainly on the long experience in substation automation systems. Common attributes for reliable power utility automation systems in all domains are quality and health. A special function having a broad application range in power utility automation systems is the scheduling of services as provided by the domain distributed energy resources (DER) used in smart grids, especially also for electric mobility. Not yet so much discussed in the context of IEC 61850 but very important for all IEDs is the impact of restart (power cycle) on the data model parameters. Non-agreed behaviour will raise problems for interoperability in multi-vendor systems.

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IEC 61970-457:2021 specifies a standard interface for exchanging dynamic model information needed to support the analysis of the steady state stability (small-signal stability) and/or transient stability of a power system or parts of it. The schema(s) for expressing the dynamic model information are derived directly from the CIM, more specifically from IEC 61970-302.
The scope of this document includes only the dynamic model information that needs to be exchanged as part of a dynamic study, namely the type, description and parameters of each control equipment associated with a piece of power system equipment included in the steady state solution of a complete power system network model. Therefore, this profile is dependent upon other standard profiles for the equipment as specified in IEC 61970-452, CIM static transmission network model profiles, the topology, the steady state hypothesis and the steady-state solution (as specified in IEC 61970-456, Solved power system state profiles) of the power system, which bounds the scope of the exchange. The profile information described by this document needs to be exchanged in conjunction with IEC 61970-452 and IEC 61970-456 profiles’ information to support the data requirements of transient analysis tools. IEC 61970 456 provides a detailed description of how different profile standards can be combined to form various types of power system network model exchanges.
This document supports the exchange of the following types of dynamic models:
• standard models: a simplified approach to exchange, where models are contained in predefined libraries of classes interconnected in a standard manner that represent dynamic behaviour of elements of the power system. The exchange only indicates the name of the model along with the attributes needed to describe its behaviour.
• proprietary user-defined models: an exchange that would provide users the ability to exchange the parameters of a model representing a vendor or user proprietary device where an explicit description of the model is not described in this document. The connections between the proprietary models and standard models are the same as described for the standard models exchange. Recipient of the data exchange will need to contact the sender for the behavioural details of the model.
This document builds on IEC 61970-302, CIM for dynamics which defines the descriptions of the standard dynamic models, their function block diagrams, and how they are interconnected and associated with the static network model. This type of model information is assumed to be pre-stored by all software applications hence it is not necessary to be exchanged in real-time or as part of a dynamics model exchange.

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IEC 61968-13:2021 specifies profiles that can be used to exchange Network Models in a Utility or between a Utility and external applications to the utility. This document provides a list of profiles which allow to model balanced and unbalanced distribution networks in order to conduct network analysis (Power flow calculation). Therefore it leverages already existing profiles (IEC 61970-45x based on IEC 61970-301 (CIM base) or profiles based on IEC 61968­11 CIM extension for Distribution). This document reuses some profiles without any change, or eventually extends them or restricts them. Moreover it proposes other profiles to reflect Distribution needs.
Use of CIM in Distribution is not a new topic. This document includes informative parts, as CIM model extensions, which could be integrated in future versions of the IEC CIM Model. These extensions have been used by some utilities for utility internal information exchange use cases and to support information exchanges between different market participants like Transmisstion System Operators (TSO), Distributed System Operators (DSO), Distributed Network Operators (DNO) and Significant Grid Users (SGU) including generators and industry.
This second edition cancels and replaces the first edition published in 2008. This edition constitutes a technical revision. This edition was pre-tested during 2016 ENTSO-E interoperability tests. The interoperability test report mentions: "Some vendors demonstrated that the transformation between distribution network and CGMES is possible. This is a first step towards the efforts to have closer integration between CGMES and profiles for exchanging distribution data (CDPSM)."

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IEC TR 62351-90-3:2021, which is a technical report, provides guidelines for efficiently handling both IT and OT data in terms of their monitoring, classification and correlations on them to deduce any possible useful outcomes about the state of the power system.
The convergence of information technologies (IT) and operational technologies (OT) refers to the integration of the systems, processes and data associated with the domains of IT and OT. This document provides guidelines for a comprehensive security monitoring for power grid components based on IT/OT convergent systems. The emphasis is about the development of a methodology and a set of recommendations for utility operators to build a general monitoring framework based on the analysis of the data collected from different IT and OT systems through network management, traffic inspection, and system activity readings. As such, the monitoring framework that this document introduces relies on the integration of management and logging information obtained using IEC 62351-7 and IEC 62351-14, respectively. Further systems and data sources from IT and OT would be considered such as the data obtained, for instance, through the IT network management using the Simple Network Management Protocol (SNMP), the passive network monitoring, and the functional characterization of control and automation processes.
This document's recommendations include the implementation of data collection, filtering and correlation mechanisms. The development of data analytics algorithms is out of the scope of this document and would be left to utility operators and owners. Finally, applications of the general monitoring framework guidelines and recommendations are provided for different power grid environments, namely for IEC 61850 substations and for Distributed Energy Resources (DER) systems.

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IEC 62325-451-10:2020 specifies a UML package for the Energy Consumption Data business process and its associated document contextual model, assembly model and XML schema for use within the European style electricity markets.
The relevant aggregate core components (ACCs) defined in IEC 62325-351 have been contextualised into aggregated business information entities (ABIEs) to satisfy the requirements of the European style market Energy Consumption Data business process.
The contextualised ABIEs have been assembled into the Energy Consumption Data document contextual model.
A related assembly model and an XML schema for the exchange of Energy Consumption information between market participants is automatically generated from the assembled document contextual model. The XML schema follows IEC Code Components management and copyright licensing

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IEC 61189-5-601:2021 specifies the reflow soldering ability test method for components mounted on organic rigid printed boards, the reflow heat resistance test method for organic rigid printed boards, and the reflow soldering ability test method for the lands of organic rigid printed boards in applications using solder alloys, which are eutectic or near-eutectic tin-lead (Pb), or lead-free alloys.
The printed boards materials for this organic rigid printed boards are epoxide woven E-glass laminated sheets that are specified in IEC 61249-2 (all parts).
The objective of this document is to ensure the soldering ability of the solder joint and of the lands of the printed boards. In addition, test methods are provided to ensure that the printed boards can resist the heat load to which they are exposed during soldering.

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IEC TR 61850-90-13:2021(E), which is a Technical Report, provides information, use cases, and guidance on whether and how to use deterministic networking technologies. Furthermore, this document comprises technology descriptions, provides guidance how to achieve compatibility and interoperability with existing technologies, and lays out migration paths. It will separate the problem statement from the possible solutions.

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IEC 62351-6:2020 specifies messages, procedures, and algorithms for securing the operation of all protocols based on or derived from the IEC 61850 series. This document applies to at least those protocols listed below:
IEC 61850-8-1 Communication networks and systems for power utility automation – Part 8-1: Specific communication service mapping (SCSM) – Mappings to MMS (ISO/IEC 9506-1 and ISO/IEC 9506-2) and to ISO/IEC 8802-3
IEC 61850-8-2 Communication networks and systems for power utility automation – Part 8-2: Specific communication service mapping (SCSM) – Mapping to Extensible Messaging Presence Protocol (XMPP)
IEC 61850-9-2 Communication networks and systems for power utility automation – Part 9-2: Specific communication service mapping (SCSM) – Sampled values over ISO/IEC 8802-3
IEC 61850-6 Communication networks and systems for power utility automation – Part 6: Configuration description language for communication in power utility automation systems related to IEDs
The initial audience for this document is intended to be the members of the working groups developing or making use of the protocols listed in Table 1. For the measures described in this specification to take effect, they must be accepted and referenced by the specifications for the protocols themselves. This document is written to enable that process.
The subsequent audience for this document is intended to be the developers of products that implement these protocols.
Portions of this document may also be of use to managers and executives in order to understand the purpose and requirements of the work.

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The common information model (CIM) is an abstract model that represents all the major objects
in an electric utility enterprise typically involved in utility operations. By providing a standard
way of representing power system resources as object classes and attributes, along with their
relationships, the CIM facilitates the integration and interoperability of network applications
developed independently by different vendors, between entire systems running network
applications developed independently, or between a system running network applications and
other systems concerned with different aspects of power system operations, such as generation
or distribution management. SCADA is modelled to the extent necessary to support power
system simulation and inter-control centre communication. The CIM facilitates integration by
defining a common language (i.e. semantics) based on the CIM to enable these applications or
systems to access public data and exchange information independent of how such information
is represented internally.
The object classes represented in the CIM are abstract in nature and can be used in a wide
variety of applications. The use of the CIM goes far beyond its application in an EMS. This
document should be understood as a tool to enable integration in any domain where a common
power system model is needed to facilitate interoperability and plug compatibility between
applications and systems independent of any particular implementation.
Due to the size of the complete CIM, the object classes contained in the CIM are grouped into
several logical Packages, each of which represents a certain part of the overall power system
being modelled. Collections of these Packages are progressed as separate International
Standards. This document specifies a Base set of packages which provide a logical view of the
functional aspects of Energy Management System (EMS) and power system modelling
information within the electric utility enterprise that is shared between all applications. Other
standards specify more specific parts of the model that are needed by only certain applications.
Subclause 4.3 of this document provides the current grouping of packages into standards
documents.

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IEC 61968-5:2020 is the description of a set of functions that are needed for enterprise integration of DERMS functions. These exchanges are most likely between a DERMS and a DMS. However, since this is an enterprise integration standard which may leverage IEC 61968-100:2013 for application integration (using web services or JMS) or other loosely-coupled implementations, there are no technical limitations for systems with which a DERMS might exchange information. Also, it should be noted that a DERMS might communicate with individual DER using a variety of standards and protocols such as IEC 61850, IEEE 2030.5, Distribution Network Protocol (DNP), Sunspec Modbus, or perhaps Open Field Message Bus (OpenFMB). One role of the DERMS is to manage this disparity and complexity of communications on the behalf of the system operator. However, the communication to individual DER is out of scope of this standard. Readers should look to those standards to understand communication to individual DER’s smart inverter.
The scope will be limited to the following use case categories:
• DER group creation – a mechanism to manage DER in aggregate
• DER group maintenance – a mechanism to add, remove, or modify the members and/or aggregated capabilities of a given group of DER
• DER group deletion – removing an entire group
• DER group status monitoring – a mechanism for quantifying or ascertaining the current capabilities and/or status of a group of DER
• DER group forecast – a mechanism for predicting the capabilities and/or status of a group of DER for a given time period in the future
• DER group dispatch – a mechanism for requesting that specified capabilities of a group of DER be dispatched to the grid
• DER group voltage ramp rate control – a mechanism for requesting that a DER group following a ramp rate curve
• DER group connect/disconnect – a mechanism to request that DER either isolate themselves, or reconnect to the grid as needed.

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IEC TR 61850-90-12:2020, which is a Technical Report, is intended for an audience familiar with electrical power automation based on IEC 61850 and related power system management, and particularly for data network engineers and system integrators. It is intended to help them to understand the technologies, configure a wide area network, define requirements, write specifications, select components, and conduct tests.
This document provides definitions, guidelines, and recommendations for the engineering of WANs, in particular for protection, control and monitoring based on IEC 61850 and related standards.
This document addresses substation-to-substation communication, substation-to-control centre, and control centre-to-control centre communication. In particular, this document addresses the most critical aspects of IEC 61850 such as protection related data transmission via GOOSE and SMVs, and the multicast transfer of large volumes of synchrophasor data.
The document addresses issues such as topology, redundancy, traffic latency and quality of service, traffic management, clock synchronization, security, and maintenance of the network.
This document contains use cases that show how utilities tackle their WAN engineering. This second edition cancels and replaces the first edition published in 2015. This edition constitutes a technical revision.
This edition includes the following significant technical changes with respect to the previous edition:
a) extension of use case with respect to distribution and customer-side applications;
b) extensions of wireless access technologies as well as power line communication ones applicable to the above-mentioned use case;
c) revisions regarding radio communication technology performance;
d) extension of network migration with respect to packet switched network;
e) a new mapping of multiprotocol label switching technology to teleprotection.

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IEC 60839-11-5:2020 specifies the Open supervised device protocol (OSDP) for electronic access control systems. This includes communication settings, commands and replies between the ACU and the peripheral devices. It also includes a mapping of mandatory and optional requirements as per IEC 60839-11-1:2013 as covered by Annex.
This document applies to physical security only. Physical security prevents unauthorized personnel, attackers or accidental intruders from physically accessing a building, room, etc.

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IEC 61970-301:2020 lays down the common information model (CIM), which is an abstract model that represents all the major objects in an electric utility enterprise typically involved in utility operations. By providing a standard way of representing power system resources as object classes and attributes, along with their relationships, the CIM facilitates the integration of network applications developed independently by different vendors, between entire systems running network applications developed independently, or between a system running network applications and other systems concerned with different aspects of power system operations, such as generation or distribution management. SCADA is modeled to the extent necessary to support power system simulation and inter-control centre communication. The CIM facilitates integration by defining a common language (i.e. semantics) based on the CIM to enable these applications or systems to access public data and exchange information independent of how such information is represented internally.
This edition reflects the model content version ‘IEC61970CIM17v38’, dated ‘2020-01-21’, and includes the following significant technical changes with respect to the previous edition:
a) Added Feeder modelling;
b) Added ICCP configuration modelling;
c) Correction of issues found in interoperability testing or use of the standard;
d) Improved documentation;
e) Updated Annex A with custom extensions;
f) Added Annex B Examples of PST transformer modelling;
g) Added Annex C HVDC use cases.

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IEC TS 61850-1-2:2020, which is a technical specification, is intended for any users but primarily for standardization bodies that are considering using IEC 61850 as a base standard within the scope of their work and are willing to extend it as allowed by the IEC 61850 standards. This document identifies the required steps and high-level requirements in achieving such extensions of IEC 61850 and provides guidelines for the individual steps.
Within that scope, this document addresses the following cases:
• The management of product-level standards for products that have an interface based on IEC 61850
• The management of domain-level standards based on IEC 61850
• The management of transitional standards based on IEC 61850
• The management of private namespaces based on IEC 61850
• The development of standards offering the mapping of IEC 61850 data model at CDC level
• The development and management of IEC 61850 profiles for domains (underlying the role of IEC TR 62361-103 and IEC TR 61850-7-6)
This document includes both technical and process aspects:
On the technical side, this document:
• Reminds the main basic requirements (mostly referring to the appropriate parts of the series which host the requirements or recommendations)
• Lists all possible flexibilities offered by the standards
• Defines which flexibilities are allowed/possible per type of extension cases
On the process side, the document covers:
• The initial analysis of how the existing IEC 61850 object models and/or communication services may be applied and what allowed extensions may be required for utilizing them in new or specific domains (including private ones). The results of that step are expected to be documented
• The extension of the IEC 61850 object models for new domains. The typical associated work is to identify existing logical nodes which can be reused "as is", to determine if existing logical nodes can be extended, or to define new logical nodes
• The purpose and process to use transitional namespaces, which are expected to be merged eventually into an existing standard namespace
• The management of standard namespaces
• The development of private namespaces

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IEC 61968-1:2020 is the first in a series that, taken as a whole, defines interfaces for the major elements of an interface architecture for power system management and associated information exchange.
This document identifies and establishes recommendations for standard interfaces based on an Interface Reference Model (IRM). Subsequent clauses of this document are based on each interface identified in the IRM. This set of standards is limited to the definition of interfaces. They provide for interoperability among different computer systems, platforms, and languages. IEC 61968-100 gives recommendations for methods and technologies to be used to implement functionality conforming to these interfaces.
As used in IEC 61968, distribution management consists of various distributed application components for the utility to manage electrical distribution networks. These capabilities include monitoring and control of equipment for power delivery, management processes to ensure system reliability, voltage management, demand-side management, outage management, work management, network model management, facilities management, and metering. The IRM is specified in Clause 3. The IRM defines the high-level view of the TC 57 reference architecture and the detailed in the relevant 61968 series, 61970 series or 62325 series. The goal of the IRM is to provide a common relevant context view for TC 57 that covers domains like transmission, distribution, market, generation, consumer, regional reliability operators, and regulators.
This third edition cancels and replaces the second edition published in 2012. This edition constitutes a technical revision.
This edition includes the following significant technical changes with respect to the previous edition:
a) update of IRM section, which has been out of date since the 2nd edition;
b) update to IRM model using ArchiMate modelling language;
c) addition of missing business functions and business objects;
d) alignment with newly released documents from the technical committee;
e) alignment with IEC 61968-100;
f) update of annexes.

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