oSIST-TP IEC/TR 62325-102:2009

Framework for energy market communications - Part 102: Energy market model example

Defines a restricted example business model of the electricity market following the Open-edi reference model ISO/IEC 14662. Shows how the modelling methodology can be applied to the energy market, and serves as the base of technology-dependent configuration examples in other parts of the IEC 62325 series.

Krovni podatki za komunikacije na energijskem trgu - 102. del: Vzorčni model za energijski trg

General Information

• Status: Not Published
• Public Enquiry End Date: 30-Dec-2009
• ICS: 29.240.30 - Control equipment for electric power systems
• ICS: 33.200 - Telecontrol. Telemetering
• Technical Committee: PSE - Power systems management
• Current Stage: 98 - Abandoned project (Adopted Project)
• Start Date: 23-May-2023
• Due Date: 28-May-2023
• Completion Date: 23-May-2023
• Ref Project: IEC/TR 62325-102 - Framework for energy market communications - Part 102: Energy market model example

Standards Content (Sample)

SLOVENSKI STANDARD
oSIST-TP IEC/TR 62325-102:2009
01-december-2009
.URYQLSRGDWNL]DNRPXQLNDFLMHQDHQHUJLMVNHPWUJXGHO9]RUþQLPRGHO]D
HQHUJLMVNLWUJ
Framework for energy market communications - Part 102: Energy market model example
Ta slovenski standard je istoveten z: IEC/TR 62325-102
ICS:
33.200 Daljinsko krmiljenje, daljinske Telecontrol. Telemetering
meritve (telemetrija)
oSIST-TP IEC/TR 62325-102:2009 en
2003-01.Slovenski inštitut za standardizacijo. Razmnoževanje celote ali delov tega standarda ni dovoljeno.

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oSIST-TP IEC/TR 62325-102:2009

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oSIST-TP IEC/TR 62325-102:2009


TECHNICAL IEC


REPORT TR 62325-102





First edition
2005-02


Framework for energy market communications –
Part 102:
Energy market model example

 IEC 2005  Copyright - all rights reserved
No part of this publication may be reproduced or utilized in any form or by any means, electronic or
mechanical, including photocopying and microfilm, without permission in writing from the publisher.
International Electrotechnical Commission, 3, rue de Varembé, PO Box 131, CH-1211 Geneva 20, Switzerland
Telephone: [phone] Telefax: [phone] E-mail: [e-mail] Web: www.iec.ch
PRICE CODE
Commission Electrotechnique Internationale
W

International Electrotechnical Commission
Международная Электротехническая Комиссия
For price, see current catalogue

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oSIST-TP IEC/TR 62325-102:2009
– 2 – TR 62325-102  IEC:2005(E)
CONTENTS
FOREWORD.4
INTRODUCTION.6
1 Scope .7
2 Normative references .7
2.1 Generic Open-edi standards .7
2.2 Sectorial Open-edi standards.7
3 Terms, definitions and abbreviations .8
3.1 Terms and definitions .8
3.2 Abbreviations .8
4 Market guide .8
4.1 General .8
4.2 Trading.9
4.3 Supply.9
4.4 Customer management.9
4.5 Scheduling and balancing .10
4.6 Metering.12
4.7 Settlement of accounts and billing.12
5 UMM market model.12
5.1 Business modelling workflow .12
5.2 Business requirement workflow .25
5.3 Analysis workflow .31
5.4 Design workflow .37

Figure 1 – Value chains and services in the energy market .9
Figure 2 – Structure of the Business Operations Map (BOM) .19
Figure 3 – Business areas.21
Figure 4 – Process areas of system operation .21
Figure 5 – Process areas of services.21
Figure 6 – Process areas of trade .21
Figure 7 – Use case system operation.22
Figure 8 – Use cases service .24
Figure 9 – Activity diagram planning process of scheduling.24
Figure 10 – Overall conceptual market activity diagram .26
Figure 11 – Use case system operation.28
Figure 12 – Business collaboration planning (scheduling) .30
Figure 13 – Activity diagram of the planning process (scheduling).31
Figure 14 – Business transaction activity diagram planning phase 1.33
Figure 15 – Business transaction activity diagram planning phase 2.35
Figure 16 – Business transaction activity diagram planning phase 3.36
Figure 17 – Conceptual class diagram of the schedule messages .37
Figure 18 – Class diagram of the schedule document .38
Figure 19 – Sequence diagram of the planning (scheduling) business process .39
Figure 20 – Sequence diagram of change of supplier.40

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TR 62325-102  IEC:2005(E) – 3 –

Table 1 – Methodology and model artefacts.13
Table 2 – Business reference model.14
Table 3 – Business area generation .14
Table 4 – Business area trading.15
Table 5 – Business area supply.15
Table 6 – Business area system operation .16
Table 7 – Business area distribution.17
Table 8 – Business area energy services .17
Table 9 – Identification of the process area planning .18
Table 10 – Identification of the process area operation .18
Table 11 – Identification of business process scheduling .19
Table 12 – Identification of the business process choice of supplier .19
Table 13 – Business operations map .20
Table 14 – Methodology and model artefacts.25
Table 15 – Business process use case scheduling (intra area).27
Table 16 – Business collaboration planning (scheduling) .29
Table 17 – Business collaboration protocol table .29
Table 18 – Methodology and model artefacts.32
Table 19 – Business transaction scheduling phase 1 .32
Table 20 – Business transaction property values .33
Table 21 – Business transaction transition table .33
Table 22 – Business transaction scheduling phase 2 .34
Table 23 – Business transaction property values .34
Table 24 – Business transaction transition table .34
Table 25 – Business transaction scheduling phase 3 .35
Table 26 – Business transaction property values .36
Table 27 – Business transaction transition table .36
Table 28 – Methodology and model artefacts.37

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oSIST-TP IEC/TR 62325-102:2009
– 4 – TR 62325-102  IEC:2005(E)
INTERNATIONAL ELECTROTECHNICAL COMMISSION
____________

FRAMEWORK FOR ENERGY MARKET COMMUNICATIONS –

Part 102: Energy market model example


FOREWORD
1) The International Electrotechnical Commission (IEC) is a worldwide organization for standardization comprising
all national electrotechnical committees (IEC National Committees). The object of IEC is to promote
international co-operation on all questions concerning standardization in the electrical and electronic fields. To
this end and in addition to other activities, IEC publishes International Standards, Technical Specifications,
Technical Reports, Publicly Available Specifications (PAS) and Guides (hereafter referred to as “IEC
Publication(s)”). Their preparation is entrusted to technical committees; any IEC National Committee interested
in the subject dealt with may participate in this preparatory work. International, governmental and non-
governmental organizations liaising with the IEC also participate in this preparation. IEC collaborates closely
with the International Organization for Standardization (ISO) in accordance with conditions determined by
agreement between the two organizations.
2) The formal decisions or agreements of IEC on technical matters express, as nearly as possible, an international
consensus of opinion on the relevant subjects since each technical committee has representation from all
interested IEC National Committees.
3) IEC Publications have the form of recommendations for international use and are accepted by IEC National
Committees in that sense. While all reasonable efforts are made to ensure that the technical content of IEC
Publications is accurate, IEC cannot be held responsible for the way in which they are used or for any
misinterpretation by any end user.
4) In order to promote international uniformity, IEC National Committees undertake to apply IEC Publications
transparently to the maximum extent possible in their national and regional publications. Any divergence
between any IEC Publication and the corresponding national or regional publication shall be clearly indicated in
the latter.
5) IEC provides no marking procedure to indicate its approval and cannot be rendered responsible for any
equipment declared to be in conformity with an IEC Publication.
6) All users should ensure that they have the latest edition of this publication.
7) No liability shall attach to IEC or its directors, employees, servants or agents including individual experts and
members of its technical committees and IEC National Committees for any personal injury, property damage or
other damage of any nature whatsoever, whether direct or indirect, or for costs (including legal fees) and
expenses arising out of the publication, use of, or reliance upon, this IEC Publication or any other IEC
Publications.
8) Attention is drawn to the Normative references cited in this publication. Use of the referenced publications is
indispensable for the correct application of this publication.
9) Attention is drawn to the possibility that some of the elements of this IEC Publication may be the subject of
patent rights. IEC shall not be held responsible for identifying any or all such patent rights.
The main task of IEC technical committees is to prepare International Standards. However, a
technical committee may propose the publication of a technical report when it has collected
data of a different kind from that which is normally published as an International Standard, for
example "state of the art".
IEC 62325-102, which is a technical report, has been prepared by IEC technical committee
57: Power systems management and associated information exchange.
The IEC 62325 series cancels and replaces IEC 62195 (2000) and its amendment (2002).
It constitutes a technical revision.
IEC 62195 (2000) dealt with deregulated energy market communications at an early stage. Its
amendment 1 (2002) points out important technological advancements which make it possible
to use modern internet technologies based on XML for e-business in energy markets as an
alternative to traditional EDI with EDIFACT and X12. The new IEC 62325 framework series for
energy market communications currently consisting of IEC 62325-101, IEC 62325-102,
IEC 62325-501, and IEC 62325-502 follows this direction and replaces IEC 62195 together
with its amendment.

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oSIST-TP IEC/TR 62325-102:2009
TR 62325-102  IEC:2005(E) – 5 –
The text of this technical report is based on the following documents:
Enquiry draft Report on voting
57/705/DTR 57/722/RVC

Full information on the voting for the approval of this technical report can be found in the
report on voting indicated in the above table.
This publication has been drafted in accordance with the ISO/IEC Directives, Part 2.
IEC 62325 consists of the following parts, under the general title Framework for energy
market communications:
Part 101: General guidelines
Part 102: Energy market model example
1
Part 201: Glossary
2
Part 3XX: (Titles are still to be determined)
3
Part 401: Abstract service model
Part 501: General guidelines for use of ebXML
Part 502: Profile of ebXML
3
Part 503: Abstract service mapping to ebXML
3
Part 601: General guidelines for use of web services
3
Part 602: Profile of Web Services
3
Part 603: Abstract service mapping to web services
The committee has decided that the contents of this publication will remain unchanged until
the maintenance result date indicated on the IEC web site under "http://webstore.iec.ch" in
the data related to the specific publication. At this date, the publication will be
• reconfirmed,
• withdrawn,
• replaced by a revised edition, or
• amended.
A bilingual edition of this document may be issued at a later date.

___________
1
 Under consideration. Because the technologies have an inherent own glossary within their standard definitions,
2)
this glossary is a placeholder for a glossary for future parts indicated with including energy market specific
terms and definitions.
2
 Under consideration. These parts for business content are mentioned for completeness only with a number
space as placeholder. They extend the original scope and require an agreed new work item proposal for further
work based on an overall strategy how to proceed.
3
 Under consideration. These technical parts are mentioned for completeness with provisional title. They extend
the original scope and require an agreed new work item proposal for further work.

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oSIST-TP IEC/TR 62325-102:2009
– 6 – TR 62325-102  IEC:2005(E)
INTRODUCTION
The market model depends on the market rules of the country or region. An incomplete list
may include the legal and regulatory framework, business rules, technical market rules
(network access, balance management, schedule management, congestion management),
identification schemas of market participants and e-business objects, metering code (service
and access to metering values), grid code (operation), distribution code (operation), and load
profiles (synthetic and analytical). The model has to comply with these rules and should
include all market participants and transactions to allow seamless communication.

This part of IEC 62325 deals with the UMM (UN/CEFACT modelling methodology) modelling
of the energy market and its result, the business and information model. The model has been
derived but is not identical with those from some existing markets. It serves as an informative
example for business processes and associated information. For the purpose of the
IEC 62325 series, and for reasons of space, the model has been simplified and shortened and
is by no means complete. Some descriptions and modelling parts are derived from existing
technology independent market models as EDIEL (http://www.ediel.org/), ETSO
(www.edi.etso-net.org/, see ETSO Scheduling System (ESS)), ERCOT (http://www.ercot.com/,
see Market Guide), VDEW (http://www.strom.de/, see Choice of Supplier). An other approach
would be to derive variations and extensions of an existing model from artefacts in a
registry/repository and business library.
Where the UML business model workflow is almost completely described, the other workflows
are complete only with focus on specific business processes within process areas such as the
process planning of scheduling and to some extent the process change of supplier. For
simplicity in the collaborations and transactions, only business failures are shown and
technical failures and business signals (as acknowledgements on the messaging level) are
omitted.

The message content is based on a energy market specific vocabulary which can be shared
over messages, business areas and business domains. Note that with the planned market
extension of the CIM (Common Information Model, IEC 61970-301) model of the power
system, the vocabulary for system operators may be derived in future from the extended CIM
acting as a knowledge based market information model. This will be treated in future parts of
the IEC 62325 series.





.

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oSIST-TP IEC/TR 62325-102:2009
TR 62325-102  IEC:2005(E) – 7 –
FRAMEWORK FOR ENERGY MARKET COMMUNICATIONS –

Part 102: Energy market model example


1 Scope
This part of IEC 62325 defines a restricted (see introduction) example business model of the
electricity market following the Open-edi reference model ISO/IEC 14662. Fundamental to the
model is the division of the business transactions into the Business Operational View (BOV)
and the Functional Service (FSV) with mapping of services between to ensure independence
of the communication technology used.
Because energy markets vary, this model example is only informative. The main purpose of
the model is to show how the modelling methodology can be applied to the energy market,
and to serve as the base of technology-dependent configuration examples in other parts of
the IEC 62325 series.
The model uses the UN/CEFACT modelling methodology UMM based on UML (Universal
Modelling Language) for the Business Operational View, but other modeling methodologies
may also be used. The modelling is done from the beginning for the whole market and its
result is the “business process and information model” which can be taken as the input for the
technology-dependent modelling in the design phase of systems and further for the Functional
Service View. See IEC 62325-501 and future parts of the IEC 62325 series for this.
2 Normative references
The following referenced documents are indispensable for the application of this document.
For dated references, only the edition cited applies. For undated references, the latest edition
of the referenced document (including any amendments) applies.
2.1 Generic Open-edi standards
ISO/IEC 14662, Information technology – Open-edi reference model
UN/CEFACT Modelling Methodology (UMM), NO90 R10 or higher
UN/CEFACT Modelling Methodology Meta Model, NO90 R10 or higher
NOTE Work is in progress at UN/CEFACT regarding the “content” of business information exchange for example
as Core Components (UN/CEFACT - Core Components Technical Specification), Core Component Library (CCL,
accessible through an registry/repository), Catalogue of Core Components (including industry groups), Common
Business Processes, UMM Business Library, XML message design rules (UN/CEFACT – XML Naming and Design
Rules (Draft 2004)).
The energy market specific vocabulary can be derived from Core Components or/and an
energy market information model.
2.2 Sectorial Open-edi standards
Market modelling based on this implies to some extent sectorial standards. At the moment, no
references are given.

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3 Terms, definitions and abbreviations
3.1 Terms and definitions
None.
3.2 Abbreviations
BIE Business Information Entity
BOV Business Operational View
CC Core Component (based on BIE)
CIM Common Information Model
DSO Distribution System Operator
DUNS Data Universal Numbering System (North America)
EAN European Article Number (Europe)
EDI Electronic Data Exchange
FOV Functional Service View
ICT Information and Communication Technology
ISO Independent System Operator
IT Information Technology
MIS Market Identification Schema
UML Unified Modelling Language
UMM UN/CEFACT Modelling Methodology
SO System Operator (Transmission, Distribution)
TSO Transmission System Operator
4 Market guide
4.1 General
In the following, an informal and conceptual textual description of the electricity market called
Market Guide is provided for basic understanding. The description is a not complete example.
Real markets may differ. Note that different time intervals are used in energy markets for
scheduling and metering.
Figure 1 shows a high-level presentation of the supply chain of energy with basically three
main phases: in the trading planning phase, energy consumption is forecast and trading is
planned. In the trading operational phase, energy is traded to meet the forecast, and
respective generation resources are allocated. The implementation of the physical energy
path from generation over the transmission and distribution network to consumption affords
co-ordinated planning of balanced schedules in the system operation planning phase for
generation, import/export and consumption. In the system operation operational phase,
energy flows directly from the producer to the customer over the transmission and distribution
network. System operation guarantees in this phase that generation meets consumption in
real-time (balancing) and that the system is reliable. Many services are needed to support the
core processes. In the settlement phase, for example, the settlement service provides the
means to bill consumption and imbalances. Any imbalance of operation (difference between
schedules and metered generation and consumption) is in the financial responsibility of the
Balance-Responsible Parties (traders and others).

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oSIST-TP IEC/TR 62325-102:2009
TR 62325-102  IEC:2005(E) – 9 –
Additionally, supporting system operation services and energy services are necessary. Each
business area has one or more market participants who initiate the business process and/or
act as stakeholder responsible for the outcome of it. Exceptions to this are energy services,
which may be outsourced and driven by various market participants following the value chain.

Services (registration, metering, settlement, billing)
Sell energy
Change of supplier
Generation
generation
Trading Supply Consumption
trading supply consumption
production
production
Net access Net access
Power flow
Transport, distribution
System operation (scheduling & balancing)
IEC  188/05

Figure 1 – Value chains and services in the energy market
4.2 Trading
There are two types of trading, bilateral contracts and trading on the spot market (power
exchange). Bilateral trading may take place over an intermediate broker. Trading may also
include seasonal products. Trading may afford a financial clearing of risks if one party is not
able to fulfil the contract.
4.3 Supply
Suppliers represent competitive retailers that sell electricity directly to eligible customers who
have the choice of supplier. Suppliers may be retail providers (without own distribution
network) or distribution utilities in the role of suppliers. Suppliers will forecast their customer
load and negotiate privately with traders to buy energy. Suppliers will communicate the
resulting schedules to the transmission system operators (see 4.5).
With supply, many services are associated (see for example 4.6 and 4.7).
4.4 Customer management
The management of customers requires the business processes change of supplier,
relocation of customer, metering and access to the metering values, change of meter,
contract for new access to the network. Because some business processes are complicated,
multi-party collaborations with shared market meta data, some markets have implemented a
centralised clearing service for all these business processes within a region.
Suppliers interact with each other and the distribution service provider (providing network
access) when they need to submit switching requests, where customers choose a new
supplier. The switching requests are processed by working with metering service providers to
obtain the initial and final meter reads, confirming switches with customers, and confirming
the switch with the relevant suppliers once the switch is approved. Switch confirmations are
also sent as notices to customers.

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4.5 Scheduling and balancing
Scheduling and balancing of transmission system operators (TSO) follows two business
processes: (1) planning of balanced scheduling, (2) operation. The first process involves the
following three phases: schedule message validation, balance validation, and system
validation.
The TSO is responsible for maintaining the real-time balance of consumption and generation
and for the reliability of the electricity system within in its region. The TSO relies on the
availability of generation capacity to provide balancing energy to maintain the electric system
within allowable reliability limits. The provision of capacity and energy are competitive
services that will be provided in the market. Generation units that can be on standby and
available to be called upon to provide energy or loads that are available to be interrupted to
relieve the need for additional energy may provide these services. These services needed for
generation or load resources to ensure reliability are called ancillary services. There are two
types of ancillary services: (1) generation reserve available to be used if needed to provide
balancing energy or loads available to be interrupted reducing the need for additional capacity
and (2) balancing energy to ensure that supply and demand are in balance or loads
interrupted to avoid the need for additional energy.
The TSO will continuously monitor the amounts of reserve capacity available across the
system to insure against unforeseen events, ranging from differences between scheduled and
actual demand to the sudden loss of a generating unit or transmission facility. If the analysis
identifies a difference, the TSO will procure a replacement reserve to ensure sufficient
capacity to deal with the projected capacity inadequacy or congestion.
As the TSO moves closer to the real-time interval in which the energy will actually be
delivered, it will continuously get additional information that improves its ability to forecast
system conditions. For instance, as the day-ahead energy schedules are finalised for a given
24-hour period, scheduling entities will submit resource plans for generators that indicate the
amounts of:
• Capacity, which is generation capacity that will be readily available if needed, but is not
actually delivered to the grid as energy.
• Energy, which is the energy that will be generated and sent to the grid to meet the
generators’ contracted amounts of load.
After evaluating the effect on the power grid of forecasted loads, schedules, transmission
system conditions and resource plans, the TSO will determine how much additional capacity
need
...