IEC TR 62325-102:2005

TECHNICAL IEC
REPORT TR 62325-102
First edition
2005-02
Framework for energy market communications –
Part 102:
Energy market model example
Reference number
IEC/TR 62325-102:2005(E)
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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
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– 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

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

– 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
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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.
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
Part 201: Glossary
Part 3XX: (Titles are still to be determined)
Part 401: Abstract service model
Part 501: General guidelines for use of ebXML
Part 502: Profile of ebXML
Part 503: Abstract service mapping to ebXML
Part 601: General guidelines for use of web services
Part 602: Profile of Web Services
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.

___________
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.
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.
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.

– 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.
.
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.
– 8 – TR 62325-102  IEC:2005(E)
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).

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.

– 10 – TR 62325-102  IEC:2005(E)
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
needs to be reserved to assure the TSO will have resources that can provide balancing
energy in real-time to maintain reliability. The TSO will procure the needed capacity services
to ensure that it is able to serve the scheduled loads as well as relieve loading on
transmission lines that appear to be constrained upon a study of the submitted schedules.
The TSO will procure balancing energy typically about 10 min before the time of actual power
flow, by which time the right amount can be predicted very accurately using short-term
forecasting tools.
Replacement reserve ancillary service providers will submit balancing energy bids when they
submit their Replacement Reserve capacity bids. Their balancing energy bids will go in the
balancing energy bid stacks for the hours for which they were awarded to provide
Replacement Reserve capacity service. Ancillary service providers will not, however, bid the
capacity that they have sold to the TSO into the market for other capacity services.
The TSO will select and deploy balancing energy in the amount necessary to keep the system
in balance and minimise the net energy needed in real time from regulation service providers.

TR 62325-102  IEC:2005(E) – 11 –
A key feature of the competitive retail electricity market is that it will be based on bilateral
transactions between buyers and sellers of energy. Balance Responsible Parties (traders,
producers and suppliers) are required to turn into the TSO balanced energy schedules of load
and energy required to generate and serve the load. The balance schedules are a result of
bilateral trade between load and resource entities. The TSO only operates the electricity
market as far as the TSO is needed to mitigate the energy imbalances. This is unlike some
other markets, where power generating companies sell electricity into a “pool” and load
serving entities (trades, suppliers) purchase from the same “pool” in an exchange where the
amount of demand and supply sets market prices for buyers and sellers.
Traders and supplier acting also in the role of traders buying energy and producers selling
energy will communicate operational information such as their bilaterally arranged balanced
schedules of loads and resources to the TSO through their scheduling entities. The TSO will
ensure that the power network can accommodate the schedules that were generated by the
bilateral market.
The TSO makes an assessment of the ancillary services needed to accommodate the bilateral
schedules and the scheduling entities are asked to either provide their share of these services
from their own resources or let the TSO purchase these services from the market on their
behalf. Market participants may self-provide all or part of their share of ancillary services. The
TSO is uniquely positioned to identify the ancillary services needed to resolve system
conditions such as capacity inadequacy and congestion, to maintain reliability, as shown in
the previous section.
The TSO, in addition to the activities described above, will help market participants plan and
manage their competitive market operations effectively by giving them timely information like
forecasts of weather, load, losses, and ancillary services requirements.
For every settlement interval, the TSO will accept balanced schedules from Balance
Responsible Parties (traders, producers and suppliers) that identify the source and
destination of contracted power flows, as well as their amount and timing. TSO will compare
the sum of these schedules to its own load forecasts, to determine balancing energy and
ancillary services requirements.
The TSO will work with traders and suppliers to procure ancillary services through a series of
markets, which the TSO will operate, and will deploy them as needed to ensure system
reliability. If the submitted schedules ultimately result in congestion of the transmission
system and the TSO needs to re-dispatch system resources to resolve the congestion, market
participants will pay for the re-dispatching or congestion costs.
In order to settle with the balance-responsible parties, the Imbalance Settlement Responsible
party will aggregate load and resource data for every settlement interval. He will then
calculate the load imbalance as the difference between scheduled and the aggregated load
data, to issue the appropriate credits and/or debits to balance-responsible parties. The same
comparison is made between aggregated energy supplied from the resources provided by the
Balance-Responsible parties and the scheduled energy to allocate the appropriate debits
and/or credits due to the resource imbalance.
The TSO will also work with distribution network providers to manage the transmission
system. Distribution network providers are also responsible for load and resource meters
installation as well as submitting meter data for all loads and resource meters that are not
directly polled by the TSO.
The TSO which acts as an ISO (Independent System Operator) may have a central premise
clearing system that will facilitate for example the customer switching process (choice of
supplier) by transmitting switch requests and meter consumption data between suppliers and
distribution network providers and keeping track of the association between premises and
suppliers. In the case where there is no central clearing system, the customer switching
process is decentralised between the suppliers and the Distribution Network Providers.

– 12 – TR 62325-102  IEC:2005(E)
Producers are the only entities that can own generation or loads that can act as resources.
They negotiate bilaterally in their role as traders with traders/power exchanges to sell their
energy, and communicate the resulting schedules to the TSO.
Balance-responsible parties can also bid into the balancing energy market and other ancillary
service markets from the resources in their portfolio. The TSO reimburses the balance-
responsible parties at the market-clearing price if the TSO selects the bid.
4.6 Metering
Metering service provider or distribution network providers in the role of Metering Service
Provider, provide meter reading and consumption information, in order to settle correctly the
balancing energy and ancillary service markets. For example, consumption information for
each supplier in the Balance-Responsible role will be needed to determine whether the actual
load matches the schedules submitted. If it did not match, the difference will be settled at the
balancing energy market-clearing price.
Most customer meters measure accumulated consumption between meter read-dates and are
typically read once per month or year. An estimate of the energy consumption for each period
(15 min for example) is needed to properly perform settlement. The estimation is done by
standard load profiles that break down monthly consumption into the above mentioned
periods for the different customer segments in the region. Some customers with load-profile
meters can meter the consumed energy within periods.
Suppliers have authorised access to the meter readings for the purpose of forecast and
billing. The optimisation of load schedules may afford the reading of load profile meters and
the access to the meter readings each day.
4.7 Settlement of accounts and billing
The financial settlement for balancing energy and ancillary services that were used by the
TSO will take place between traders and the TSO and is performed by the Settlement
Responsible Party. Settlement of the balancing energy will be based on the load imbalance
and resource imbalances from each Balance Responsible Party. The load imbalance is the
difference between the scheduled load and actual load from each trader. Resource imbalance
is the difference between the scheduled energy and actual energy for each trader. The actual
load and energy amounts are derived from the load and resource meter readings. For
example, if a trader’s actual energy supplied from the resources it represents is insufficient to
match the scheduled energy in the balanced schedule it provided to the TSO, that trader
would be required to reimburse the TSO for the balancing energy the TSO procured, at the
market clearing price or other price. On the other hand, if the TSO accepts a balancing energy
bid from the ancillary services market, the TSO will pay for it as appropriate at the market-
clearing price.
Suppliers bill their customers based on the metered consumption and tariffs. Transmission
and distribution providers bill the producers and customers that have access to the network
with a network usage fee.
5 UMM market model
NOTE The model uses the Unified Modelling Language (UML) notation.
5.1 Business modelling workflow
5.1.1 General
The purpose of business modelling according to UMM is:
• to understand the structure and dynamics of the business domain,

TR 62325-102  IEC:2005(E) – 13 –
• to ensure that all users, standards developers and software providers have a common
understanding of the business domain,
• to understand the daily business in the business domain independent of any technical
solution,
• to create categories to help partition the business domain that enables an iteration plan to
complete the model,
• to structure the model in the form of a Business Operations Map (BOM)
• to capture the justification for the project,
• to identify the stakeholders concerned with the modelled domain, some of whom will be
independent of the processes within the domain.
Business areas can contain groups of process called process areas which in turn include
individual business processes. Business processes identified in the business modelling
workflow consist of business collaborations and transactions described in the requirement
workflow and in more detail in the analysis workflow.
After this general structuring, UML use case diagrams are organised as groups within UML
packages that use the names of business areas.
The main focus of business modelling workflow is on business domain, business area and
business process areas understanding, not on processes, which are only identified.
Table 1 shows the workflow for methodology and model artefacts.
Table 1 – Methodology and model artefacts
Workflow Methodology Model artefacts (BOM with UML)
Business modelling Domain analysis Business area, process area (UML packages)
Use case analysis Use cases
Process discovery Identification of processes
Activity modelling Activity diagrams

5.1.2 Business process discovery and identification
For the high-level business domain, analysis worksheets are used.
5.1.2.1 Business reference model
Table 2 shows the worksheet business reference model for the business domain energy
market. All worksheets, this and the following ones, are examples only.

– 14 – TR 62325-102  IEC:2005(E)
Table 2 – Business reference model
Form: Describe business reference model
Business reference model name Energy market
Industry segment Electricity
Domain scope The domain scope covers all stages from the planning phase to the settlement
phase of generation, transmission and distribution of electricity, and energy
services with focus on the exchange of market information and documents.
In the electricity market, energy is generated, traded (wholesale on power
exchange or bilateral) and supplied (retail) to the customer (consumption). At
every moment, generation and supply should be in balance and the security of
the network should be granted. Producer and customer have non-discriminated
access to the energy network and customers can chose their supplier. The
commercial use of networks for transmission and distribution is transparent to
the market participants regardless of the physical structure (voltage level,
hierarchy, control areas involved). The market also needs services to support
the core functions such as registration of market participants with access to the
network, exchange of market metadata, ancillary services, change of supplier,
metering, settlement of imbalances, settlement of accounts, and billing.
Business areas Generation, trading, supply, system operation, transmission and distribution,
energy services.
Business justification The business model is intended to enable e-business communication between
electricity market participants in an efficient way with low transaction cost based
on a common understanding of processes and transactions.
Constraints The legislation and rules are different in different countries. The deregulation
process is not co-ordinated in different countries or regions. The deregulation
process accelerates splitting and merging of companies. The companies and
markets are more and more international. Due to the increased competition, the
prices to end-users may be reduced. Environmental problems may prevent
necessary system resources.
5.1.2.2 Description of business areas

Table 3 shows the worksheet for the business area generation.
Table 3 – Business area generation
Form: Describe business area
Business area name Generation
Description Generation of electricity according to the schedules given by traders. Providing
auxiliary services for system operators.
Scope Generation of electricity and providing auxiliary services.
Boundary of the business area Generation
References …
Constraints Environmental problems may prevent necessary system resources. There is a
resistance to nuclear power plants. There is a resistance to pollut
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