Nordic TSO message exchange model - Ediel · PDF fileBRS for Nordic trading system Nordic Ediel Group Page: 6 Replaced Elbas with Intraday Updated NTC and NEG member list Addition

BRS (Business Requirement Specification)

Nordic trading system

A market model for data exchange

Business process: Nordic trading system Version: 1.6.A

Status: Approved by NEG Date: April 19th, 2017

BRS for Nordic trading system

Nordic Ediel Group Page: 2

CONTENT

1 Introduction ................................................................................................................................... 4

1.1 Background ........................................................................................................................................ 4 1.2 Nordic Energy Domain Model ........................................................................................................... 4 1.3 NTC .................................................................................................................................................... 4 1.4 References ......................................................................................................................................... 4 1.5 Terms and notation ........................................................................................................................... 5 1.6 Change log ......................................................................................................................................... 5

2 Overview of the Nordic energy market domain ............................................................................... 8

2.1 Trade in the overall context (Domain model) ................................................................................... 8 2.2 Breakdown of the trading phase ....................................................................................................... 9 2.3 Overview of information exchange for “operational markets” ...................................................... 11 2.4 Overview of information exchange for “day-ahead and intraday markets” ................................... 14 2.5 Market implementations ................................................................................................................. 16

2.5.1 FRR-A market ............................................................................................................................... 16 2.5.2 Reserve options market (only used in Denmark and Norway) .................................................... 16 2.5.3 Day-ahead market ....................................................................................................................... 16 2.5.4 Intraday market ........................................................................................................................... 16 2.5.5 Frequency activated reserves market .......................................................................................... 16 2.5.6 Balance regulation market .......................................................................................................... 17 2.5.7 Bilateral trade between System operators .................................................................................. 17

3 Harmonised roles used in Nordic trading system ........................................................................... 18

3.1 Trade Responsible Party .................................................................................................................. 20

4 Business Entity View, Nordic trading system .................................................................................. 21

4.1 Business Entity View, Business entities ........................................................................................... 21 4.2 Business Entity View, Business entity states ................................................................................... 22

4.2.1 FRR-A market states .................................................................................................................... 22 4.2.2 Reserve option market states (Norway and Denmark) ............................................................... 22 4.2.3 Day-ahead market states ............................................................................................................ 23 4.2.4 Intraday market ........................................................................................................................... 23 4.2.5 Frequency activated reserves market states ............................................................................... 24 4.2.6 Balance regulation market states ................................................................................................ 24 4.2.7 Bilateral trade between System operators states ....................................................................... 25

5 Process areas within Nordic trading system ................................................................................... 26

5.1 Process area: Trade on FRR-A market ............................................................................................. 26 5.2 Process area: Trade on Reserve options market (Norway and Denmark) ...................................... 26 5.3 Process area: Trade on day-ahead market ...................................................................................... 27 5.4 Process area: Trade on intraday market ......................................................................................... 29 5.5 Process area: Trade on Frequency activated reserves market ....................................................... 31 5.6 Process area: Trade on the Balance regulation market .................................................................. 32 5.7 Process area: Bilateral trade between System operators ............................................................... 34

6 Business Data View; Nordic trading system ................................................................................... 35

6.1 NEG Currency Exchange Rate Document ........................................................................................ 35 6.1.1 Attribute usage; NEG Currency Exchange Rate Document .......................................................... 36 6.1.2 Dependencies ............................................................................................................................... 36

6.2 NEG Spot Bid Document, version 2.0 .............................................................................................. 37 6.2.1 Attribute usage; NEG Spot Bid Document, version 2.0 ................................................................ 38

http://www.ediel.org/hjem.htm



6.2.2 Dependencies ............................................................................................................................... 40 6.3 NEG Area Specification Document, version 2.0 .............................................................................. 41

6.3.1 Class diagram; NEG Area Specification Document, version 2.0 .................................................. 41 6.3.2 Attribute usage; NEG Area Specification Document, version 2.0 ................................................ 42 6.3.3 Dependencies ............................................................................................................................... 43

6.4 NEG Auction Specification Document, version 1.1 ......................................................................... 44 6.4.1 Class diagram; NEG Auction Specification Document, version 1.1 .............................................. 44 6.4.2 Attribute usage; NEG Auction Specification Document, version 1.1 ........................................... 46 6.4.3 Dependencies ............................................................................................................................... 48

6.5 NEG ERRP Reserve Bid Document, version1.0 ................................................................................ 50 6.5.1 Class diagram; NEG ERRP Reserve Bid Document, version 1.0 .................................................... 50 6.5.2 Attribute usage: NEG ERRP Reserve Bid Document, version 1.0 ................................................. 51 6.5.3 Dependencies ............................................................................................................................... 53

6.6 NEG ERRP Reserve Allocation Result Document, version 1.0 ......................................................... 54 6.6.1 Class diagram: NEG ERRP Reserve Allocation Result Document, version 1.0 .............................. 54 6.6.2 Attribute usage; NEG ERRP Reserve Allocation Result Document, version 1.0 ........................... 55 6.6.3 Dependencies ............................................................................................................................... 57

6.7 NEG ECAN Allocation Result Document, version 3.0 ...................................................................... 58 6.7.1 Class diagram; NEG ECAN Allocation Result Document, version 3.0 ........................................... 58 6.7.2 Attribute usage: NEG ECAN Allocation Result Document ............................................................ 59 6.7.3 Dependencies ............................................................................................................................... 60 6.7.4 Market Operator usage of NEG ECAN Allocation Result Document: ........................................... 61

6.8 NEG ECAN Publication Document, version 1.1 ................................................................................ 62 6.8.1 Class diagram; NEG ECAN Publication Document, version 1.1 .................................................... 62 6.8.2 Attribute usage; NEG ECAN Publication Document, version 1.1 ................................................. 64 6.8.3 Dependencies ............................................................................................................................... 66

7 Business rules ............................................................................................................................... 67

7.1 General ground rules ....................................................................................................................... 67




1 Introduction

1.1 Background

Today the Nordic TSOs exchange documents based on several different formats and standards, such as Ediel (DELFOR/MSCONS), NOIS XML documents based on ENTSO-E IGs and Excel documents. In addition, the Nordic TSOs have communications towards other European countries, such as Germany, the Netherlands and Poland, using even more standards.

For efficiency reasons the four Nordic TSOs have established the NEG (Nordic Ediel Group) Technical Committee (NTC) for migration of the document exchanges towards one common document standard. The aim is to define document exchange models that can be used for all document exchanges between the actors in the Nordic energy market, Nordic TSOs and Market Operators.

This document is a Business Requirement Specification (BRS) detailing the document exchanges related to trade in the Nordic energy market. The focus of the document is the business aspects of the document exchanges and the basis for the document is the ENTSO-E ERRP Implementation Guide [1] and ECAN Implementation Guide [1], together with the ebIX®, EFET and ENTSO-E Harmonised role model [3].

Note: The documents used in this BRS is not necessarily the documents used today, but should be the documents to be used in the future.

1.2 Nordic Energy Domain Model

A Nordic Energy market Domain model, giving an overall overview of the structure and processes used in the Nordic Energy market, can be found in [12].

1.3 NTC

The document is written by NTC (NEG Technical Committee), with the following members at the time of publication:

Steering group: Nordic Ediel Group (NEG): Anne Stine Hop, Statnett, [email protected] Christian Odgaard, Energinet.dk, [email protected] Jari Hirvonen, Fingrid, [email protected] Jan Owe, Svenska kraftnät, [email protected] Jon-Egil Nordvik (NTC convenor), Statnett, [email protected] Minna Arffman (convenor), Fingrid, [email protected] Oscar Ludwigs, Svenska kraftnät, [email protected] Ove Nesvik (secretary), EdiSys, [email protected]

NTC: Christian Odgaard, Energinet.dk, [email protected] Fedder Skovgaard, Energinet.dk, [email protected] Jan Owe, Svenska kraftnät, [email protected] Jari Hirvonen, Fingrid, [email protected] Jon-Egil Nordvik, Statnett (convenor), [email protected] Kim Dahl, Statnett, [email protected] Minna Arffman (convenor), Fingrid, [email protected] Ole Fredsø Weigelt, Energinet.dk, [email protected] Ove Nesvik, EdiSys (secretary), [email protected]

1.4 References

[1] ENTSO-E implementation guides, see ENTSO-E, EDI Work Products Library :

ENTSO-E Modelling Methodology, EMM


mailto:[email protected]

















https://www.entsoe.eu/publications/electronic-data-interchange-edi-library/work%20products/Pages/default.aspx



ENTSO-E UCTE SO-SO Process

ENTSO-E Scheduling System, ESS

ENTSO-E Settlement Process, ESP

ENTSO-E Reserve Resource Planning, ERRP

ENTSO-E Capacity Allocation and Nomination, ECAN

ENTSO-E Capacity Auction Specification document, ECAN

ENTSO-E Publication Document, ECAN

ENTSO-E Status Report, ESR

ENTSO-E Acknowledgement process [2] ECP (Energy communication platform) Functional Specifications [3] The Harmonised Role Model, ENTSO-E, ebIX® and EFET, see ENTSO-E, EDI Work Products Library [4] UN/CEFACT Unified Modelling Methodology (UMM), see http://umm-dev.org/ [5] UN/CEFACT XML Naming and Design Rules (NDR), see

http://www.unece.org/cefact/xml/xml_index.html [6] ebIX Modelling methodology and process models (EMD), see http://www.ebix.org/ [7] Ediel Implementation guides, see http://www.ediel.org/ [8] Nordic Ediel Group, Common Nordic XML rules and recommendations, see http://www.ediel.org/ [9] Nordic Ediel Group, BRS for the Nordic TSO Determine transfer capacity model, see

http://www.ediel.org/ [10] Nordic Ediel Group, BRS for the Nordic TSO Scheduling and Ancillary Services Process, see

http://www.ediel.org/ [11] Nordic Ediel Group, BRS for Nordic operational system, see http://www.ediel.org/ [12] Nordic Energy Market Domain Model, see http://www.ediel.org/ [13] Agreement regarding operation of the interconnected Nordic power system (System Operation

Agreement) http://www.entsoe.eu/fileadmin/user_upload/_library/publications/nordic/operations/060613_entsoe_nordic_SystemOperationAgreement_EN.pdf

1.5 Terms and notation

The term document is used instead of message, when this is applicable. However when referencing ENTSO-E document names, the ENTSO-E name will be used, e.g. message, report or document.

When the term TSO is used in this document, it normally includes also the Market Operator.

Documents are described by a class diagram showing the full set of attributes in the related xml schema. In addition, the usage of the document is described by one or more tables detailing the usage of each attribute. Optional attributes from the class diagram, not used in the specific data exchange, are omitted from the table. In addition the cardinalities, e.g. [0..1], may be stricter in the detailed descriptions than in the original ENTSO-E documents.

1.6 Change log

Ver/rel/rev Changed by Date Changes

1.6.A Ove Nesvik 20170331 Addition of Price category type codes to NEG ERRP Allocation Result document:

Z01 Buying Z02 Selling Z03 Average

Updated Energinet logo on the front page 1.5.A Ove Nesvik 20170213 Updated logos on the front page

Replaced Nord Pool and NPS with Market Operator

Replaced Elspot with Day-ahead


https://www.entsoe.eu/publications/electronic-data-interchange-edi-library/work%20products/Pages/default.aspx

http://umm-dev.org/

http://www.unece.org/cefact/xml/xml_index.html

http://www.ebix.org/

http://www.ediel.org/






http://www.entsoe.eu/fileadmin/user_upload/_library/publications/nordic/operations/060613_entsoe_nordic_SystemOperationAgreement_EN.pdf

http://www.entsoe.eu/fileadmin/user_upload/_library/publications/nordic/operations/060613_entsoe_nordic_SystemOperationAgreement_EN.pdf



Replaced Elbas with Intraday

Updated NTC and NEG member list

Addition of Business Types to NEG Auction Specification Document, version 1.1:

o A95 Frequency containment reserve o A97 Manual frequency restoration reserve

Additions to NEG ERRP Reserve Bid Document and NEG ERRP Reserve Allocation Result Document:

o “A02 No” to Divisible o “A01 Yes” to BlockBid

1.4.B Ove Nesvik 20161209 Rename of ERRP Reserve Bid Document, version 5.0 to NEG ERRP Reserve Bid Document, version 1.0 (du to Nordic additions

Addition of Business Types to NEG ERRP Reserve Bid Document, version 1.0:

o A95 Frequency containment reserve o A97 Manual frequency restoration reserve o Z51 Commercial consumption

1.4.A Ove Nesvik 20161206 Changed version of NEG Auction Specification Document to version 1.1:

o Addition of a Direction o Addition of Requested Quantity

NEG ECAN Publication Document: o Changed version to version 1.1 o Average Price is removed from the class

diagram o Addition of “A38 Reconciliation Responsible”

as Receiver Role

Overview of information exchange for “day-ahead and intraday markets” (sequence diagram)

o Addition of “Average price report from Market Operator to Reconciliation Responsible

1.3.A Ove Nesvik 20161027 Addition of clarifying text

Textual corrections

Removal of the Lithuanian currency “LTL”

Measure Unit Quantity is made required in ERRP Reserve Allocation Result Document

NEG ECAN Allocation Result Document: o The following attributes are made optional:

Bid Document Identification Bid Document version Auction Identification Contract Identification

o Contract Type “A02 Weekly” is removed

NEG ECAN Publication Document: o Addition of Document Types “A38 Reserve

Allocation Result” and “A44 Price document”

The ERRP Activation Document is moved to BRS for Operate

NEG ERRP Reserve Allocation Result Document: o Tendering Patty is made required [1]

Chapter “7 Business Rules” has been rewritten




Appendixes have been removed

1.2.A Ove Nesvik 20160718 Addition of clarifying text

Addition of links between the document exchange overview and detailed document.

Addition of cardinalities in detailed document description tables

Addition of when to use optional data elements where relevant

The NEG Spot Market Bid Document is extended with System Bid Identification and Bid Responsible Identification

The NEG ECAN Allocation Result Document is extended with Bid Responsible Identification

1.1.C Ove Nesvik 20150122 Lithuania has gone over to Euro, hence the currency LTL, Lithuanian Litas has been removed

1.1.C Ove Nesvik 20150122 The Reason code Z19 has been replaced by B21 (Official exchange rate approved)

Update of “EPD Publication Document” to “ECAN Publication Document” (incl. new XML schema)

Rename of “NEG Day Ahead Detailed Sales Report” to “NEG ECAN Allocation Result Document” (incl. new XML schema)

1.1.B Ove Nesvik 20140905 Addition of MW (mega Watt) as Measure Unit Quantity and Measure Unit Price in the ERRP Reserve Allocation Result Document

Senders Bid Document and Senders Bid Document Version are removed from the Activation Document class diagram

1.1.A Ove Nesvik 20140207 The Business Type Z11 (LFC) is updated to A12 Secondary control (FRR-A)

Update of all class diagrams to latest ENTSO-E version

Update of codes and text according to latest MR status

Addition of two new elements in the NEG Spot Bid Document

o Exclusive Group Identification o Minimum Acceptance Ratio

Update of class diagrams related to ENTSO-E documents; the class diagrams include the complete ENTSO-E class diagram and the tables exclude the elements not used in the Nordic countries

1.0.A Ove Nesvik 20130930 First version approved by Nordic Ediel Group




2 Overview of the Nordic energy market domain

2.1 Trade in the overall context (Domain model)

The Domain model describes the main business process areas needed to have a well-functioning energy market. The model is important for having a common and agreed understanding on how the energy market works as a basis for development of common methods for exchange of information.

Figure 1: UseCase diagram: Domain model

The domain model of the energy market covers all stages from the structuring of the market until the settlement and billing of consumption and transport of energy, with a focus on the exchange of information:

Exchange of master data including the Change of Supplier processes

Trade on different markets, including ancillary services, bilateral trade, etc.

Planning of production, consumption, exchange and transport

Operation

Measuring of production, consumption, exchange and transport

Settlement

Billing The Nordic trading system process is a part of the process area Trade. For a more elaborated description of the processes include in the domain model, see [12].




2.2 Breakdown of the trading phase

In the rest of this document the Business area (UseCase) Trade is further elaborated.

Figure 2: UseCase diagram: The Nordic trading system process

The Business Area Trade outlined in Figure 2, concerns principally buying and selling of energy between Balance responsible parties, including trade through the Market operators (e.g. Power exchanges), for fulfilling their contractual obligations. In addition, the trading phase includes the trade between Balance responsible parties and the System operators for managing the operational need for regulation. In the rest of this document the green UseCases, i.e. Trade on FRR-A (Frequency Restoration Reserves, Automatic, earlier LFC) market, Trade on Reserve options market, Trade on Frequency activated reserves market, Trade on day-ahead market, Trade on Balance regulation market and Bilateral trade between System operators are further elaborated, while the UseCase Determine transfer capacity is documented in a separate BRS [9].




Figure 3 Activity diagram: The Nordic trading system process

Bilateral trade is restricted to a given Market Balance Area, while trade on the day-ahead, Adjustment and Balance regulation markets may be between Market Balance Areas, i.e. through the Market operator, System operators or between System operators. The Reserve options market is a tool to ensure enough fast reserves for the Balance regulation market, especially during wintertime when the load is high. The market is based on weekly contracts. There is no common Reserve options market within the Nordic power system and currently only used in Denmark and Norway. The Frequency activated reserves market is a market that is weekly, daily and hourly based. In addition to national markets, the Frequency activated reserves are traded between the Nordic TSO’s on a bilateral basis.




2.3 Overview of information exchange for “operational markets”

Figure 4 Sequence diagram: Information exchange overview for “operational markets”




Process area Arrow Documentation

Trade on FRR-A market

1. Area Specification NEG Area Specification Document, see: 6.3

2. Auction Specification NEG Auction Specification Document, see: 6.4

3. FRR-A bids NEG ERRP Reserve Bid Document, see 6.5

4. FRR-A contracts NEG ERRP Reserve Allocation Result Document, see 6.6

5. FRR-A summary report NEG ECAN Publication Document, see 6.8

Trade on Reserve option market

6. Area specification NEG Area Specification Document, see: 6.3

7. Auction specification NEG Auction Specification Document, see: 6.4

8. Reserve option bids NEG ERRP Reserve Bid Document, see 6.5

9. Reserve option contracts NEG ERRP Reserve Allocation Result Document, see 6.6

10. Reserve option market summary report

NEG ECAN Publication Document, see 6.8

Trade on Frequency activated reserves market


12. Frequency activated reserves bids

NEG ERRP Reserve Bid Document, see 6.5

13. System operator to System operator trade

Currently by telephone

14. Frequency activated reserves contracts

NEG ERRP Reserve Allocation Result Document, see 6.6

15. Frequency activated reserves summary


Trade on Balance regulation market

16. Balance regulation bids NEG ERRP Reserve Bid Document, see 6.5

17. Balance regulation bids NEG ERRP Reserve Bid Document, see 6.5

18. Balance regulation bid list Made available for System operators via NOIS

Bilateral trade between System operators

19. Request bilateral trade Currently: By telephone Later: ERRP Activation Document

(Status = A10, Ordered), See [11]

20. Confirm/Reject bilateral trade

ERRP Activation Document (Status = A07, Activated or A09, cancelled) See [11]

21. Bilateral trade report NEG ECAN Publication Document, see 6.8

Operation (activation) 22. Activate or deactivate bids

Currently: By telephone Later: ERRP Activation Document (Status = A10,

Ordered), documented in BRS for Nordic operational system [11]

23. Activation response Currently: By telephone Later: ERRP Activation Document (Status = A07,

Activated or A09, cancelled), docu-mented in BRS for Nordic operational system [11]

24. Activated or deactivated bids information

ERRP Activation Document, documented in BRS for Nordic operational system [11]

25. Balance regulation market price

NEG ECAN Publication Document, documented in BRS for Nordic operational system [11]

Reporting 26. Price report NEG ECAN Publication Document, documented in BRS for Nordic operational system [11]

27. Price report NEG ECAN Publication Document, documented in BRS for Nordic operational system [11]

28. Activated or deactivated bids






29. Daily exchange report NEG ECAN Publication Document, documented in BRS for Nordic operational system [11]

30. Traded volume NEG ECAN Publication Document, documented in BRS for Nordic operational system [11]

31. Balance regulation market price


Table 1: ENTSO-E documents used in the Nordic trading system Figure 4 shows the main electronic documents exchanged between the Resource providers (market participants), System operators, Market information aggregator, MOL Responsible and the Market operator. Reporting to the Imbalance settlement responsible is shown in a separate BRS. As seen from the diagram the basic information exchange is similar for the Trade on FRR-A market, the Reserve options market and the Frequency activated reserves market. First an Auction specification document is sent from the System operator to the Resource providers (market participants), then the Resource providers send in their bids to the System operator and finally the resulting contracts are sent to the Resource providers. The Auction specification document contains information about the available auctions, products, areas and cut-off times. Trade in the Frequency activated reserves market can in addition be executed between the System operators. Summary of the trade on the Frequency activated reserves market is sent to the Market information aggregator. For the Balance regulation market, the Auction specification is not sent explicitly, but follows the area definitions from the day-ahead market. In addition to the bids, the Resource providers must send Production schedules and Ancillary services schedules; including the result from the Frequency activated reserves market see [10]. The Balance regulation bids are sent from the System operators to the MOL Responsible and made available for the System operators as a sorted list of bids. When needed the System operators may, in addition to the trade on the Balance regulation market, trade bilaterally. Today this trade is executed using telephone. After the bids have been received the bids may be activated. Each activated bid are reported back to the Resource provider in question and reported to the Market information aggregator. After the operational phase, on a daily basis, the activated and deactivated bids, and Balance regulation market prices are distributed to the Resource providers. Summaries of traded volumes for consumption and production per Bidding area may be sent from the System operator to the Resource provider. In addition to the information exchange shown in the diagram above, the marginal prices and total quantity bought are made available on a web-server for the different markets. The Resource providers are cautioned by Balance Responsible Parties, which may be responsible for consumption, production or both.

In addition to the “operational markets” described above the Market operator run the day-ahead and intraday markets, which is described below.




2.4 Overview of information exchange for “day-ahead and intraday markets”

Figure 5 Sequence diagram: Information exchange overview for the day-ahead and intraday markets


Day-ahead market 1. Area specification NEG Area Specification Document, see: 6.3

2. Area specification NEG Area Specification Document, see: 6.3


4. Day-ahead Bid NEG Spot Bid Document, see 6.2

5. Day-ahead Bid Status Request

Will be handled by an API, i.e. no xml schema

6. Day-ahead Bid Status NEG Spot Bid Document, see 6.2

7. Day-ahead sales report





8. Day-ahead detailed sales report

NEG ECAN Allocation Result Document, see 6.7

9. Day-ahead summary sales report




11. Day-ahead exchange between bidding areas

ESS Schedule document, documented in BRS for the Nordic TSO Scheduling and Ancillary Services Process [10]



13. Day-ahead schedules per BRP


14. Day-ahead schedules per BRP


15. Validated day-ahead schedules per BRP


16. Currency exchange rate

NEG Currency Exchange Rate Document, see 6.1

Intraday market 17. Intraday bid WEB interface

18. Intraday detailed sales report

NEG ECAN Allocation Result Document, see 6.7

19. Intraday summary sales report

Proposal for future implementation from NEG: NEG ECAN Publication Document, see 6.8

20. Intraday exchange schedules between bidding areas


21. Intraday exchange schedules between bidding areas


22. Intraday schedules per BRP


23. Intraday schedules per BRP


24. Average prices report Proposal for future implementation from NEG: NEG ECAN Publication Document, see 6.8



27. Validated intraday schedules per BRP


Table 2: ENTSO-E documents used for trade on day-ahead and intraday markets

On the day-ahead market, hourly power contracts are traded daily for physical delivery in the next day's 24-hour period. After closure of the day-ahead market, the intraday market opens for trade for the next day. The intraday market is open for trade 24/7 (intraday). The NEG Currency exchange rate document is sent daily to the System Operators and to other actors on request.




2.5 Market implementations

2.5.1 FRR-A market FRR-A (Frequency Restoration Reserves, Automatic, earlier LFC) market bids are based on FRR-A areas, prices and sizes. FRR-A regulation is always carried out where it is cheapest, provided there are no network restrictions. 2.5.2 Reserve options market (only used in Denmark and Norway) Reserve option bids are based on area, product (production and reduced consumption), option price, and size (a minimum of 25 MW). Offers must state potential restrictions regarding duration of continuous activation and interval between activations. Such restrictions result in price reductions based on agreed terms. One marginal price is set for each bidding area. This means that the production reserves and decreased consumption reserves always get the same price although the Reserve Allocator might choose to buy just production, just reduced consumption or both. Unavailability of contracted resources shall be reported immediately to the Reserve Allocator. The option price will then be reduced according to agreed terms. 2.5.3 Day-ahead market The balance demand on the day-ahead market assures that the predictable part of the difference between the participant's energy supply and obligations are outbalanced in the day-ahead market. The day-ahead market is a common power market for the Nordic, Baltic and other countries with an implicit capacity auction on the interconnectors between the Market Balance Areas. 2.5.4 Intraday market Intraday is a continuous cross border intra-day market that covers the Nordic countries, Germany, and Baltic where adjustments to trades done in the day-ahead market are made until one hour prior to delivery. The intraday market connects its participants within and across the borders of the Nordic, German and Baltic power markets. All trades done on intraday are implicit utilising cross border capacity. Available cross border capacity for intra-day trading is updated after each executed trade. The participants are, in some of the countries obligated to report the trades done on intraday to their local System Operator (SO). 2.5.5 Frequency activated reserves market The Frequency activated reserves are split into Frequency Containment Reserves, Disturbance (FCR-D earlier FDR) and Frequency Containment Reserves, Normal (FCR-N earlier FNR) in Norway, Sweden and Denmark east (DK2), while Denmark west (DK1) uses only Frequency bias (Primary Reserve). In Norway and Denmark the marginal price is set per bidding area and unavailability of contracted reserves will induce a penalty according to agreed terms. In Sweden the price setting follow pay-as-bid principles, while Norway is using marginal pricing. Acquired reserves may be traded between the System operators.




In Sweden the bids from the Resource provider and the acceptance from the System operator is done in two steps, first step two days before the operational day and the second step the day before the operational day. Both steps are ended with a schedule from the Resource provider. 2.5.6 Balance regulation market Balance regulation bids are based on bidding area, price and size and must state restrictions regarding duration of continuous activation and interval between activations. Activation time, minimum duration, maximum duration and resting time is based on national rules. The participants are allowed to correct the bids until 45 minutes before the hour. It is not allowed to correct bids back in time. Balance regulation is always carried out where it is cheapest, provided there are no network restrictions. All the regulations are implemented in the national markets. This means there can be different rules for the national markets, which obviated the need to harmonise all the market rules before the start of the Nordic (international) balance regulation market. All imbalance prices are set per bidding area. 2.5.7 Bilateral trade between System operators There are two types of trade, and related exchange, as a result of ramping deviations for HVDC cables. The two types of trade are trade for system reasons (counter purchases) and trade for balance reasons. Ramping deviation is the calculated deviation from the trading plan as a result of ramping of HVDC cable. This discrepancy is cleared by trade rules for the connection. Trade for system reasons and trade for balance reasons are based on the terms of the Balance regulation market. The agreements are between national and foreign bidding areas. Trade for system reasons and trade for balance reasons have two different purposes. Trade for balance reasons is a part of the handling of the Balance regulation market in the Nordic area. Trade for system reasons is trade to deal with bottlenecks and errors. For system reasons, the price is agreed for each trade and calculated using the "pay as bid" principle. For trade for balance reasons there are separate agreements for the exchange and pricing (market conditions for Balance regulation market).




3 Harmonised roles used in Nordic trading system In Figure 6 and in definitions below the relevant parts of the ebIX®, EFET and ENTSO-E Harmonised role model are outlined.

Figure 6: Outline of the Harmonised role model within the scope of the Nordic trading system

Definitions (from the ebIX®, EFET and ENTSO-E Harmonised role model) :

Balance responsible party: A party that has a contract providing financial security and identifying balance responsibility with the Imbalance Settlement Responsible of the market balance area entitling the party to operate in the market. This is the only role allowing a party to buy or sell energy on a wholesale level.

Additional information: The meaning of the word "balance" in this context signifies that the quantity contracted to provide or to consume must be equal to the quantity really provided or consumed. Such a party is often owned by a number of market players. Equivalent to "Program responsible party" in the Netherlands. Equivalent to "Balance responsible group" in Germany. Equivalent to "market agent" in Spain.




Trade Responsible Party: A party who can be brought to rights, legally and financially, for any imbalance between energy bought and consumed for all associated metering points.

Note: A power exchange without any privileged responsibilities acts as a Trade Responsible Party. Additional information: This is a type of Balance Responsible Party.

Imbalance settlement responsible: A party that is responsible for settlement of the difference between the contracted quantities and the realised quantities of energy products for the Balance Responsible Parties in a Market Balance Area. Note: The Imbalance Settlement Responsible has not the responsibility to invoice. The Imbalance Settlement Responsible may delegate the invoicing responsibility to a more generic role such as a Billing Agent.

Market information aggregator: A party that provides market related information that has been

compiled from the figures supplied by different actors in the market. This information may also be published or distributed for general use.

Note: The Market Information Aggregator may receive information from any market participant that is relevant for publication or distribution.

Market operator: The unique power exchange of trades for the actual delivery of

energy that receives the bids from the Balance Responsible Parties that have a contract to bid. The market operator determines the market energy price for the market balance area after applying technical constraints from the system operator. It may also establish the price for the reconciliation within a metering grid area.

Metered Data Aggregator: A party responsible for the establishment and qualification of

metered data from the Metered Data Responsible. This data is aggregated according to a defined set of market rules.

MOL Responsible: Responsible for the management of the available tenders for all

Acquiring System Operators to establish the order of the reserve capacity that can be activated.

Resource Provider: A role that manages a resource object and provides the schedules

for it. Reserve allocator: Informs the market of reserve requirements, receives tenders

against the requirements and in compliance with the




prequalification criteria, determines what tenders meet requirements and assigns tenders.

System Operator: A party that is responsible for a stable power system operation

(including the organisation of physical balance) through a transmission grid in a geographical area. The SO will also determine and be responsible for cross border capacity and exchanges. If necessary he may reduce allocated capacity to ensure operational stability.

Transmission as mentioned above means "the transport of electricity on the extra high or high voltage network with a view to its delivery to final customers or to distributors. Operation of transmission includes as well the tasks of system operation concerning its management of energy flows, reliability of the system and availability of all necessary system services." (definition taken from the UCTE Operation handbook Glossary).

Note: Additional obligations may be imposed through local market rules.

Functional Group: A collection of metering points for consumption and generation

within a market balance area.

Resource Object: A resource that can either produce or consume energy and that is reported in a schedule. Additional information: This is a type of Functional Group

Market Balance Area: A geographic area consisting of one or more Metering Grid Areas

with common market rules for which the settlement responsible party carries out a balance settlement and which has the same price for imbalance. A Market Balance Area may also be defined due to bottlenecks.

Reserve Object: A resource technically pre-qualified using a uniform set of standards to supply reserve capabilities to a System Operator associated with one or more metering points and tele-measuring devices.

In the Nordic countries NOIS will perform the roles of Market operator, Market information aggregator and MOL Responsible.

3.1 Trade Responsible Party

In the diagrams describing the markets the term Trade Responsible Party is used, even if the actor is a Trader, without Balance responsibility. In the detailed document description both Balance responsible parties and Trade Responsible Parties may be identified.




4 Business Entity View, Nordic trading system

4.1 Business Entity View, Business entities

In addition to the domains defined in the ebIX®, EFET and ENTSO-E Harmonised role model (see chapter 3) a series of entities have been identified as relevant for the Business area Trade. These entities are shown below:

Figure 7: Document entities relevant for trade in the Nordic energy market




4.2 Business Entity View, Business entity states

The lifecycle of a business entity may be described as a flow of business entity states, which represents the different business entity states a business entity can exist in. Below is shown the lifecycle of some of the business documents exchanged in Trade processes. 4.2.1 FRR-A market states To be done. 4.2.2 Reserve option market states (Norway and Denmark)

Figure 8: Business entity states for the Reserve option market




4.2.3 Day-ahead market states

Figure 9: Business entity states for the day-ahead market

4.2.4 Intraday market

Figure 10: Business entity states for the intraday market




4.2.5 Frequency activated reserves market states To be done

4.2.6 Balance regulation market states

Figure 11: Business entity states for the Balance regulation market




4.2.7 Bilateral trade between System operators states

Figure 12: Business entity states for bilateral trade between System operators




5 Process areas within Nordic trading system

5.1 Process area: Trade on FRR-A market

The Trade on FRR-A (Frequency Restoration Reserves, Automatic, earlier LFC) market is expected to be agreed as a common Nordic market, with new rules. The process will be specified when available and agreed by the Nordic countries.

5.2 Process area: Trade on Reserve options market (Norway and Denmark)

Figure 13: UseCase: Trade on Trade on Reserves option market

The documents exchanged within the Trade on Reserves option market process are sent between Resource providers and the Reserve Allocator. Today the role Reserve Allocator is played by the TSOs, i.e. Energinet and Statnett.




Figure 14: Activity diagram: Trade on Reserves option market

As seen from the diagram above, the bids are collected, accumulated by the Reserve Allocator as a merit order list (sorted list of bids) for each area, with accumulated quantity and cost shown along with each bid. The Reserve Allocator selects the highest bid to use to fulfil the requirements for Reserve options. Once satisfied the contracts are sent to the Resource provider and the price and total quantity are published on the web.

5.3 Process area: Trade on day-ahead market




Figure 15: UseCase: Trade on day-ahead market In the power system, a balance between production and consumption is always necessary. The balance demand on the day-ahead market assures that the predictable part of the difference between the participant's energy supply and obligations are outbalanced in the day-ahead market.

Figure 16: Activity diagram: Trade on day-ahead market

A prerequisite for using the Area specification document is that the grid model has been distributed from the System operators to the Market operator and the Balance responsible parties. On the day-ahead market, hourly power contracts are traded daily for physical delivery in the next day's 24-hour period. The price calculation is based on the balance between bids and offers from all market participants – finding the intersection point between the market’s supply curve and demand curve. This trading method is referred to as equilibrium point trading, auction trading, or simultaneous price setting.




The price mechanism in day-ahead market adjusts the flow of power across the interconnectors - and also on certain connections within the Norwegian and Swedish grids - to the available trading capacity given by the Nordic transmission system operators. Thus, day-ahead market is a common power market for the Nordic countries with an implicit capacity auction on the interconnectors between the Market Balance Areas. All participants who meet the requirements set by the Market Operators are given access to the Day-ahead market. However, day-ahead market participants must have a balancing agreement with the respective transmission system operator or through a third party. The NEG Currency exchange rate document is sent daily to the System Operators and to other actors on request. Key features of the Nordic day-ahead market concept:

Implicit auction The day-ahead market concept is based on bids for purchase and sale of hourly contracts using three different bidding types: hourly bids, block bids and flexible hourly bids that cover some or all of the 24 hours of the next day

Grid congestion management at the interconnections between the Nordic countries and within Norway and Sweden, price mechanisms are used to relieve grid congestion (bottlenecks), by introducing different Market Balance Area prices. Within Finland and Denmark, grid congestion is managed by counter-trade purchases based on bids from generators.

Area prices The total geographic market is divided into bidding areas; these may become separate price areas if the contractual flow of power between bid areas exceeds the capacity allocated for day-ahead contracts by the transmission system operators. When such grid congestion develops, two or more area prices are created

System price The day-ahead market's system price is also denoted "the unconstrained market clearing price". This is because the system price is the price that balances sale and purchase in the exchange area while not considering any transmission constraints. When there actually are no constraints between the bidding areas, the area prices are all equal to the system price.

5.4 Process area: Trade on intraday market

Figure 17: UseCase: Trade on intraday market




The intraday market is a tool for Trade Responsible parties to adjust their balance until 1 hour before delivery starts. Trade Responsible parties need to trade especially if the production or consumption plans change after daily day-ahead Auction. The parties on the intraday market are producers, consumers and traders. The intraday market document transmission cycle is composed of the following phases:

1. In the intraday market, Trade responsible parties sends bids to the intraday trading system at the Market operator. Bids can be sent 24/7. After publication of day-ahead results (appr. 14:00 CET) trading day-ahead hours begin. Trading continue for the specific hour products until 1 hour before delivery starts.

2. The trading system continuously and in real time matches the incoming bids if the bid price meet. Bids can be left in all bidding areas and the system automatically only match bids between different areas if there is now congestion between the areas in question.

3. Several times per hour the Trade Schedule per bidding area is sent to the TSOs. Prices and volume per Trade Responsible Party is sent to Parties if requested.




Figure 18: Activity diagram: Trade on intraday market

5.5 Process area: Trade on Frequency activated reserves market

The Trade on Frequency activated reserves market is expected to be redone as a common Nordic market, with new rules. The process will be specified when available and agreed by the Nordic countries.




5.6 Process area: Trade on the Balance regulation market

Figure 19: UseCase diagram: The Nordic Balance regulation market process

Figure 19 shows the process Trade on the Nordic Balance regulation market and the participating actors. The Business process is further described below.

Figure 20: Activity diagram: The Nordic Balance regulation market process




The Balance regulation market is a tool for the System operators and must be able to handle all unpredictable differences between planned and actual exchange in the delivery phase on short notice. Active bidders on the Balance regulation market must be able to regulate their delivery and usage within a given time defined by the market rules. This means that only producers and large consumers bid actively without the buyers responding to the price. All other participants remain passive. Their purchases/sales are settled deriving from the imbalance between weighed values for delivery, usage and contracted fixed energy supplies/obligations. An overview of how the trading of balancing services across borders is facilitated within Europe can be found in [13]. As seen from Figure 20, the bids are collected, accumulated and then presented for the System operator, by the MOL Responsible, as a sorted list of bids. The Nordic Balance regulation market document transmission cycle is composed of the following phases:

1. In the national Balance regulation market, Balance responsible parties sends bids to the System operators on a day-ahead basis. Bids may be for both up and down regulation and be corrected during the operational phase (e.g. within 45 minutes before operation). The System operator activates up or down regulation according to the lowest bids.

2. The national System operator forwards all the bids to the MOL Responsible. 3. When there is a need to perform balance regulation, and provided there are no network

restrictions, the operator checks with the MOL Responsible list of sorted bids to find the cheapest unused bid. If it is within the operator’s area he or she activates the bid, otherwise he or she calls the System operator with the cheapest unused bid

Related documents are defined, according to the UMM Business Data View [4], in chapter 6. In the Nordic market NOIS act as Market operator and MOL responsible. Tertiary reserve is a rescheduling action used for the restoration of Primary and Secondary reserve and to cater for a high rate of change of demand or generation, demand forecast errors or short term plant losses. Two types of Tertiary reserve activation are possible:

Schedule Activated Tertiary Control Reserve (SATCR): is activated with relation to the predefined time-frame of exchange schedules, e.g. 15 minutes. A special exchange scheduling procedure is used. It may include exchange rescheduling between TSOs, a special kind of exchange schedule is used.

Directly Activated Tertiary Control Reserve (DATCR): can be activated at any time, independent from a time-frame of exchange schedules. It is activated by manual action at any time and may also include call-up reserve contracts between TSOs. In this case, the activation procedure results in a dynamically changing exchange pattern.

In Denmark (for emergency in DK2), Finland, Norway and Sweden the DATCR type is used for activations in the Balance regulation market. Except for emergency in DK2, Denmark uses SATCR.




5.7 Process area: Bilateral trade between System operators

Figure 21: UseCase diagram: Bilateral trade between System operators

Figure 21 shows the process Bilateral trade between System operators and the participating actors (System operators). The Business process is further described below.

Figure 22: Activity diagram: Bilateral trade between System operators

The request for Bilateral trade between System operators is currently, and in the foreseeable future, done by telephone. Specification of the actual documents to be exchanged is postponed to a later stage. A Bilateral trade between System operators may result in an update of break point plans and/or operational schedules see Nordic Ediel Group, BRS for the Nordic TSO Scheduling and Ancillary Services Process, see http://www.ediel.org/ [10]. The Trade rejected state occurs if there is a negative answer on a request for a bilateral trade.




6 Business Data View; Nordic trading system

6.1 NEG Currency Exchange Rate Document

This is a Nordic document, which not will be specified by ENTSO-E.

Figure 23: Class diagram: NEG Currency Exchange Rate Document

The document is used in the following exchanges:

Table 2: ENTSO-E documents used for trade on day-ahead and intraday markets: o 15, Currency exchange rate

The NEG Currency Exchange Rate Document is sent daily from the Market Operator to the System Operators and to other actors on request. The Document must cover a full market day and contain exchange rates for all Nordic currencies and Euro. The NEG Currency exchange rate document is based on the NordPool exchange rates document from NOIS, however with some changes to the header. The general rule for calculating the Currency Exchange Rate is:

Reference Currency * Currency Exchange Rate = Target Currency




6.1.1 Attribute usage; NEG Currency Exchange Rate Document

Document Attribute Cl. Code and description

NEG Currency exchange rate document

Currency Exchange Rate Document

Document Identification

[1] Unique identification of the document

Document Version [1] Fixed 1

Document Type [1] Z07 Currency exchange rate document

Sender Identification [1] Identification of the party who is sending the document

Sender Role [1] A11 Market operator

Receiver Identification

[1] Identification of the party who is receiving the schedules

Receiver Role [1] A04 System operator Z05 Trader (Used for non-balance responsible traders) A08 Balance responsible party

Creation Date Time [1] Date and time for creation of the document

Currency Exchange Rate Date Time

[1] The day for which the Currency Exchange Rate is valid

Currency Exchange Rate

Reference Currency [1] Reference currency Any valid ISO 3 letter currency code, such as: DKK Danish Kroner EUR EURO NOK Norwegian Kroner RUB Russian Ruble SEK Swedish Kronor

Target Currency [1] Target currency Any valid ISO 3 letter currency code, such as: DKK Danish Kroner EUR EURO NOK Norwegian Kroner RUB Russian Ruble SEK Swedish Kronor

Currency Exchange Rate

[1] Currency Exchange Rate

Reason

Reason Code [1] B17 Price based on preliminary exchange rate (The exchange rate is preliminary and will be updated when an official currency exchange rate is available)

B21 Official exchange rate approved (The official exchange rate has been approved)

Reason text [0..1] Not used

Table 3: Usage of NEG Currency Exchange Rate Document

6.1.2 Dependencies None




6.2 NEG Spot Bid Document, version 2.0

This is a Nordic document, which not will be specified by ENTSO-E.

Figure 24: Class diagram: NEG Spot Bid Document, version 2.0





Table 2: ENTSO-E documents used for trade on day-ahead and intraday markets: o 4, Day-ahead Bid o 6, Day-ahead Bid Status

6.2.1 Attribute usage; NEG Spot Bid Document, version 2.0


NEG Spot Bid Document

Spot Market Bid Document


[1] A Bid Document for a given set of time series and a given bid period must have a unique identification assigned by the sender of the document for all transmissions to the receiver. All additions, modifications, or suppressions for the time series and bid period must use the same identification. Limitations, Day-ahead:

One document can contain: o Either Hourly bids or Block bids o Only one Portfolio o Only one area o Only one trading day

Document Version

[1] Version of the document being sent. A document may be sent several times, each transmission being identified by a different version number that starts at 1 and increases sequentially.

Document Type [1] A24 Bid document Z17 Spot Market Bid Status Report

Process Type [1] A01 Day-ahead

Sender Identification

[1] Identification of the party who is sending the document

Sender Role [1] For Spot Market Bid: Z05 Trader (Used for non-balance responsible traders) A08 Balance responsible party

For Spot Market Bid Status report: A11 Market operator



Receiver Role [1] For Spot Market Bid: A11 Market operator

For Spot Market Bid Status report: Z05 Trader (Used for non-balance responsible traders) A08 Balance responsible party

Creation Date Time

[1] Date and time for creation of the document

Bid Time Interval

[1] The beginning and ending date and time of the period covered by the document

Domain [1] Balance Market Area

Subject Party [1] Identification of the owner of a portfolio (account)

Subject Role [1] Z05 Trader (non-balance responsible party) A08 Balance responsible party

Spot Market Bid Time Series

Bid Identification

[1] Unique ID of the bid

Portfolio Identification

[1] Identification of the portfolio (account) in question





Auction Identification

[0..1] A unique identification of the set of specifications that clearly defines the auction to which the bid is addressed

Bid Type [1] Day-ahead : Z01 Hourly bid Z02 Block bid Z03 Flexible hourly bid Z04 Profile block bid

Business Type [1] A02 Internal trade

Bidding Area

[1] The identification of the Market Balance Area where the bids are valid.

Measure Unit Quantity

[1] MAW MW

Currency [1] Any valid ISO 3 letter currency code, such as: DKK Danish Kroner EUR EURO NOK Norwegian Kroner RUB Russian Ruble SEK Swedish Kronor

Measurement Unit Price

[1] MWH MWh

Divisible [0..1] Used to indicate conversion of block bids. Always True if used. An indication whether or not each element of the tender maybe partially accepted or not.

Linked Bid Identification

[0..1] Only used in the day-ahead market.

System Bid Identification

[0..1] A system generated Bid Identification. Only used in the Bid Status Report.

Exclusive Group Identification

[0..1] Only used for block bids in day-ahead. A unique identification of a set of bids (Block bids, Profile block bids, Flexible hourly bids) where bidder will get an acceptance of one or more of the bids, but the result will not have an Acceptance Ratio exceeding 100 (100 %).

Bid Responsible Identification

[0..1] The Identification of the user that last modified the order. Only used in the Bid Status Report.

Period

Time Interval [1] For flexible block bids the Time interval is always the whole day.

For block bids the Time interval defines the period of the bid.

For hourly bids the Time interval cover the relevant period of the day.

Resolution [1] For flexible block bids the Resolution is the length of the bid. The bid can be activated whenever during the day.

For block bids the Resolution is the length of the bid, i.e. the resolution is the same as the length of the Time interval.

For hourly bids the Resolution is always 1 hour.

Bid Interval

Pos [1] The position of the observation in a time series, i.e.:

Always 1 for standard block bids and flexible block bids

1-24 (23 or 25) for hourly bids

Bid Qty Price

Sequence [1] Sequence number of price step.





For day-ahead block bids and flexible hourly bids the sequence is always 1 The day-ahead has step increment

Selling Qty [0..1] Use either Selling or Buying Qty

Buying Qty [0..1] Use either Selling or Buying Qty

Price [1] The price might be negative and contain decimals

Conversion Price

[0..1] Only used for block bids in day-ahead (still optional), stating the price for which price block bids are converted from block bid to hourly bid (only valid for curtailment)

Minimum Acceptance Ratio

[0..1] Only used for Block and Profile block bids in day-ahead. Minimum acceptance ratio (%) allows the bidder to define lowest possible acceptance degree for the bid. Valid values 0-100, where 0 means fully curtailable and 100 means not curtailable.

Table 4: Usage of NEG Spot Bid Document, version 2.0

6.2.2 Dependencies

Document

type Process

type Bid type Linked Bid

Identification Divisible Pos Minimum

Acceptance Ratio

A24 Bid docu-ment

Z17 Spot Market Bid Status Report

A01 Day-ahead

Z01 Hourly bids Not used Not used 1-24 (23/25) Not used

Z02 Block bids If linked If divisible Always 1 If curtailable

Z03 Flexible hourly bids

Not used Not used Always 1 Not used

Z04 Profile block bids

If linked Not used Always 1 If curtailable

Table 5: Dependency matrix for NEG Spot Bid Document, version 2.0




6.3 NEG Area Specification Document, version 2.0

The NEG Area Specification Document is a new document needed in the Nordic countries. The document has not yet been specified by ENTSO-E. 6.3.1 Class diagram; NEG Area Specification Document, version 2.0

Figure 25: Class diagram: NEG Area Specification Document, version 2.0





Table 1: ENTSO-E documents used in the Nordic trading system: o 1, Area Specification o 6, Area specification

Table 2: ENTSO-E documents used for trade on day-ahead and intraday markets: o 1, Area specification o 2, Area specification

6.3.2 Attribute usage; NEG Area Specification Document, version 2.0 The area specification document reflects the Nordic (including the Baltic countries) grid model. A prerequisite is therefore that the recipient has installed the same grid model. The information needed is currently being distributed from the Market Operator as a REQOTE document on weekly basis. The Market connection points document is currently made available as downloadable CSV document from the Market Operator and lists all Nordic connection points and which Market Balance Area they are situated in.


NEG Area Specification Document

Area Specification Document



Document Type [1] Z05 Area specification document Z06 Market connection points document

Process Type [1] Currently used: A01 Day-ahead Z04 Reserve option market (Nordic code) Possible future use: A02 Intraday (The area specification defined for the day-ahead market

(A01, Day-ahead) is used today) A28 Primary reserve process, i.e. Frequency activated reserves market

(The area specification defined for the day-ahead market (A01, Day-ahead) is used today)

A29 Secondary reserve process, i.e. FRR-A market A30 Tertiary reserve process, i.e. Balance regulation market (The area

specification defined for the day-ahead market (A01, Day-ahead) is used today)


Sender Role [1] A04 System operator A11 Market operator A34 Reserve Allocator



Receiver Role [1] A08 Balance responsible party A11 Market operator


Document Time Interval


Validity period

The Validity period class may be repeated [1..*]

Validity Start [1] Date and time

Validity End [0..1] Date and time




Area specification details

Only used for Document type “Z05, Area specification document”

Area Identification [1] Unique ID of the area

Border connection

The Border connection class may be repeated [0..*]

Border Component Type (ENTSO-E Asset Type List)

[1] Day-ahead and intraday: A01 Tieline (A high voltage line used for cross border energy

interconnections) A02 Line (A specific electric line within a country) Z02 Split busbar

Border Component Identification

[1] Identification of the Border component

Connection detail

Used for the Market connection points document (Document Type = “Z06, Market connection points document”) and when the Border connection class identifies a Line or a Tieline

Component Type [1] Z01 Busbar Z02 Split busbar

Component Identification

[1] Identification of the Border component

Area Identification [0..1] Unique ID of the area

Table 6: Usage of NEG Area Specification Document, version 2.0

6.3.3 Dependencies

Document type Process type

Sender role

Receiver role

Border Component type (Asset Type List)

Component type (Asset Type List)

Z05 Area specification document

A01 A04 A11

A11 A08

A01 A02 Z02

Z01 Z02

Z04 A34 A08 A01 A02

Z01

Z06 Market connection points document

A01 A04 A11

A11 A08

Z01 Z02

Table 7: Dependency matrix for NEG Area Specification Document, version 2.0




6.4 NEG Auction Specification Document, version 1.1

6.4.1 Class diagram; NEG Auction Specification Document, version 1.1 The Auction specification document is based on the Capacity auction specification document from the ENTSO-E ECAN Capacity Auction Specification Document IG, see [1].

Figure 26: Class diagram: NEG Auction Specification Document, version 1.1





Table 1: ENTSO-E documents used in the Nordic trading system: o 2, Auction Specification o 7, Auction specification o 11, Auction specification

Table 2: ENTSO-E documents used for trade on day-ahead and intraday markets: o 3, Auction specification




6.4.2 Attribute usage; NEG Auction Specification Document, version 1.1 The NEG Auction Specification Document is based on the ENTSO-E ECAN Auction Specification Document, but is related to the ERRP process.


Auction specification document

Auction Specification Document




Document Type [1] Z03 Auction specification document

Process Type [1] A01 Day-ahead A19 Intraday accumulated

Note: This process concerns a single intraday process where only intraday evolutions occur through version changes.

A28 Primary reserve process A29 Secondary reserve process A30 Tertiary reserve process Z04 Reserve option market (Nordic code)



Sender Role [1] A11 Market operator A34 Reserve Allocator


[0..1] Identification of the party who is receiving the schedules Required except when used for “general publication”

Receiver Role [0..1] A08 Balance responsible party Required except when used for “general publication”


Document Time Interval


Domain [1] The domain that cover the time series in the document

Auction Time Series [1..*]


[0..1] Unique ID of the auction Usage: see dependency matrix below

Business Type [1] A01 Production A04 Consumption A06 External trade without explicit capacity A12 Secondary control (used for Frequency Restoration Reserve, FRR-A,

earlier called LFC) A95 Frequency containment reserve A97 Manual frequency restoration reserve Z02 Frequency bias (Nordic code) Z03 FCR-N Frequency activated normal reserve (earlier FNR) (Nordic

code) Z06 FCR-D Frequency activated disturbances reserve (earlier FDR)

(Nordic code)

Auction Type [1] A01 Implicit

Bidding Period [1] The beginning and ending date and time of the bidding period within which Capacity Traders can submit a bid to the Transmission Capacity Allocator

In Area [1] Market Balance Area as defined for the relevant market. The Market Balance Area must be within the Domain (see header).




Out Area [1] Same as In Area

Contract Type [1] A01 Daily A02 Weekly A03 Monthly A07 Intraday contract

Delivery Period [1] This information provides the start and end date and time when the energy is consumed or produced

Allocation Mode [1] A01 Order by price with pro rata A03 First come – First served

Payment Terms [0..1] A01 Pay as bid A02 Pay as cleared Usage: see dependency matrix below


[1] MAW MW

Measure Unit Price [1] See ENTSO-E code list

Currency [0..1] Any valid ISO 3 letter currency code, such as: DKK Danish Kroner EUR EURO NOK Norwegian Kroner RUB Russian Ruble SEK Swedish Kronor

Only used if a Max- or a Min Price is stated.

Curve Type [1] A01 Sequential fixed size block A03 Variable sized Block A04 Overlapping breakpoint A05 Non-overlapping breakpoint

Cancelled [0..1] A01 True A02 False Only required if a cancellation, i.e. if cancelled, the content shall be “A01 = true”

Max Price [0..1] Dependent on market Usage: see dependency matrix below

Min Price [0..1] Dependent on market Usage: see dependency matrix below

Direction [0..1] A01 Up A02 Down A03 Up and down Dependent on market

Classification Period [1]

Start Time [1] Start time within a day for the time frame relevant for the Auction Identification in question.

End Time [1] End time within a day for the time frame relevant for the Auction Identification in question.

Requested Quantity [0..*]

Time Interval [1] The start and end date and time of the time interval of the period in question

Resolution [1] The resolution defining the number of periods that the time interval is divided

Interval [1..*]

Pos [1] The position of the observation in a time series




Qty [1] The quantity for the interval in question

Auction description [0..1]

The Auction Description class provides the textual description of the auction and its market rules to clarify information that is not formally defined (e.g. the time constraints for a peak product). Line No [1] The number of a line within a textual description

Line Text [1] The textual content of a line

Reason [0..1]

The Reason class may provide any coded or textual information that is necessary to completely describe a change to the auction specification or its eventual cancellation.

Reason Code [1] A code providing the information in respect to a change or cancellation of an auction. 999 Errors not specifically identified

Reason Text [0..1] Textual explanation of the reason code Shall be used for error code 999

Table 8: Usage of NEG Auction Specification Document, version 1.1

6.4.3 Dependencies

Document

type Process

type Auction

ID Business

type Auction Type Contract Type Pay-

ment Terms

Max Price

Min Price

Z03 Auction specifi-cation document

A01 Day-ahead

A02 Internal trade

A01 Implicit A01 Daily A02

A19 Intraday accumulated

A02 Internal trade A01 Implicit A07 Intraday contract

A01

A28 Primary reserve process, i.e. Frequency activated reserves market

Z02 Frequency bias (Nordic code)

A01 Implicit A01 Daily

A02

Z03 Frequency Containment Reserves, Normal (FCR-N earlier FNR) (Nordic code)

A01 Implicit A01 Daily A02 Weekly A03 Monthly A07 Intraday

contract

A01 A02

Z06 Frequency Containment Reserves, Disturbance (FCR-D earlier FDR) (Nordic code)

A01 Implicit A01 Daily A02 Weekly A03 Monthly A07 Intraday

contract

A01 A02

A29 Secondary reserve process, i.e. FRR-A market

A12 Secondary control (A time series concerning secondary reserve) (FRR-A, earlier LFC)

A01 Implicit A02 Weekly

A01 A02

Z30 Tertiary reserve process, i.e. Balance regulation market

A01, Production A02 Internal trade A04, Consumption

A01 Implicit A07 Intraday contract

N/A




Z04 Reserve option market

A01, Production A02 Internal trade A04, Consumption

A01 Implicit A01 Daily A02 Weekly

A02

Table 9: Dependency matrix for NEG Auction Specification Document, version 1.1




6.5 NEG ERRP Reserve Bid Document, version1.0

6.5.1 Class diagram; NEG ERRP Reserve Bid Document, version 1.0 The NEG Reserve bid document is based on the ERRP Reserve Bid Document for Reserve Tenders from the ENTSO-E ERRP IG, see [1].

Figure 27: Class diagram: NEG ERRP Reserve Bid Document, version 1.0





Table 1: ENTSO-E documents used in the Nordic trading system: o 3, FRR-A bids o 8, Reserve option bids o 12, Frequency activated reserves bids o 16, Balance regulation bids o 17, Balance regulation bids

6.5.2 Attribute usage: NEG ERRP Reserve Bid Document, version 1.0


Reserve Bid Document

Reserve Bid Document




Document Type [1] A24 Bid document

Process Type [1] A28 Primary reserve process, i.e. Frequency activated reserves market

A29 Secondary reserve process, i.e. FRR-A market A30 Tertiary reserve process, i.e. Balance regulation market Z04 Reserve option market (Nordic code)


Sender Role [1] A08 Balance responsible party



Receiver Role [1] A11 Market operator (TSOs) A34 Reserve Allocator A35 MOL Responsible (NOIS)


Reserve Bid Time Interval


Domain [1] National or Nordic area (in the future)

Subject Party [1] The party responsible for the bid

Subject Role [1] A08 Balance responsible party

Reserve Bid Time Series

Reserve Bid Identification

[1] Unique ID of the bid given by the sender (Resource Provider)


[1] Auction identification from the connected Auction specification document if available, else a code identifying the auction or market (to be defined when implemented)

Business Type [1] A01 Production A04 Consumption A12 Secondary control (FRR-A, Frequency Restoration Reserve

(earlier LFC)) A95 Frequency containment reserve A97 Manual frequency restoration reserve Z02 Frequency bias (Primary reserves) (Nordic code) Z03 FCR-N, Frequency Containment Reserves, Normal (earlier

called FNR) (Nordic code) Z06 FCR-D, Frequency Containment Reserves, Disturbance

(earlier called FDR) (Nordic code) Z35 Commercial Z36 Reserve




Z50 Commercial wind production Z51 Commercial consumption

Acquiring Area [1] The area where the resource is contracted for use

Connecting Area [1] The area where the resource is located


[1] The unit of measurement used for the quantities expressed within the time series. It is recommended that this be always expressed in megawatts (code MAW).

Currency [0..1] The currency used for the monetary amount expressed within the time series. Required if a price is stated

Measure Unit Price [0..1] The unit of measurement used for the price expressed within the time series (e.g. MWh or kW per unit). Required if a price is stated

Divisible [1] A01 Yes A02 No

Block Bid [1] A01 Yes A02 No

Reserve Object [0..1] E.g. Station Group or Regulation object Usage: see dependency matrix below

Direction [1] A01 Up A02 Down A03 Up and down

Minimum Activation Quantity

[0..1] Dependent on national rules

Measure Unit Energy Price

[0..1] The unit of measurement used for the price of energy expressed within the time series. (MW per unit (code MAW), MWh per unit (code MWH), etc.). A Measure Unit Energy Price is required only if there is an Energy Price specified.

Contract type [0..1] A01 Daily A02 Weekly A03 Monthly A07 Intraday contract Usage must be specified when implemented.

Contract Identification

[0..1] Optional element. Usage must be specified when implemented.

Activation Duration [0..1] The time needed before a regulation is effective. Number of minutes for up or down regulation. Only used in the Balance regulation market. Required used if the unit has this constraint.

Resting Duration [0..1] The time between the end of activation and the start of the next activation. Number of minutes for the resting time. Only used in the Balance regulation market. Required used if the unit has this constraint.

Minimum Duration [0..1] The minimum time a regulation can be effective. Number of minutes an up or down regulation at least must be effective. Only used in the Balance regulation market. Required used if the unit has this constraint.




Maximum Duration [0..1] The maximum time a regulation can be effective. Number of minutes an up or down regulation maximum can be effective. Only used in the Balance regulation market. Required used if the unit has this constraint.

Gradient Up [0..1] Available ramping up (specified as MW/minute). Only used in the Balance regulation market. Required used if the unit has this constraint.

Gradient Down [0..1] Available ramping down (specified as MW/minute). Only used in the Balance regulation market. Required used if the unit has this constraint.

Period



Interval

Pos [1] The position of the observation in a time series

Qty [1] The quantity for the interval in question

Price [0..1] The price expressed for each unit of quantity Usage must be specified when implemented.

Energy Price [0..1] The price of the energy if used Usage must be specified when implemented.

Table 10: Usage of NEG ERRP Reserve Bid Document, version 1.0

6.5.3 Dependencies

Document

type Process

type Business

type Reserve Object

A24 Bid docu-ment


Z02 Frequency bias (Nordic code) Z03 Frequency Containment Reserves, Normal

(FCR-N earlier FNR) (Nordic code)

Optional


Optional

A29 Secondary reserve process, i.e. FRR-A


Optional

A30 Tertiary reserve process, i.e. Balance regulation market

Z35 Commercial Z36 Reserve Z49 Commercial production Z50 Commercial wind production Z51 Commercial consumption

Z04 Reserve option market (Nordic code)

A01 Production A04 Consumption

Table 11: Dependency matrix for NEG ERRP Reserve Bid Document, version 1.0




6.6 NEG ERRP Reserve Allocation Result Document, version 1.0

The NEG ERRP Reserve Allocation Result Document is based on the ENTSO-E Reserve allocation result document from the ENTSO-E ERRP IG, see [1].

6.6.1 Class diagram: NEG ERRP Reserve Allocation Result Document, version 1.0

Figure 28: Class diagram: NEG ERRP Reserve Allocation Result Document, version 1.0





Table 1: ENTSO-E documents used in the Nordic trading system: o 4, FRR-A contracts o 9, Reserve option contracts o 14, Frequency activated reserves contracts

6.6.2 Attribute usage; NEG ERRP Reserve Allocation Result Document, version 1.0


Reserve Allocation Result Document

Reserve Allocation Result Document

Document Identification [1] Unique identification of the document


Document Type [1] A38 Reserve Allocation Result (Operational bids)

Process Type [1] Z01 Frequency activated reserves market Z02 FRR-A market Z03 Balance regulation market Z04 Reserve option market Z05 Bilateral trade


Sender Role [1] A11 Market operator (TSO) A34 Reserve Allocator

Receiver Identification [1] Identification of the party who is receiving the schedules

Receiver Role [1] A04 System operator A08 Balance responsible party A11 Market operator (NOIS)


Reserve Bid Time Interval [1] The beginning and ending date and time of the period covered by the document

Domain [1] Nordic area, National Area, Market Balance Area.

Allocation Time Series

Time Series Identification [1] The identification of the time series instance

Reserve Bid Identification [0..1] Not used in the Bilateral trade between System operator process

Tendering Party [1] The ID of the tendering party, i.e. System operator or Balance responsible party Usage must be specified when implemented.

Auction Identification [0..1] If there is no Auction Specification Document, the usage of the Auction ID must be specified by the implementation project

Business Type [1] A01 Production A04 Consumption A12 Secondary control (FRR-A, Frequency Restoration

Reserve (earlier LFC)) A95 Frequency containment reserve A97 Manual frequency restoration reserve Z02 Frequency bias (Primary reserves) (Nordic code) Z03 FCR-N, Frequency Containment Reserves, Normal

(earlier called FNR) (Nordic code) Z06 FCR-D, Frequency Containment Reserves, Disturbance

(earlier called FDR) (Nordic code)

Acquiring Area [1] The area where the resource is contracted for use

Connecting Area [1] The area where the resource is located




Contract Type [0..1] A01 Daily A02 Weekly A03 Monthly A06 Long term contract Usage must be specified when implemented

Contract Identification [0..1] See Table 13 below

Measure Unit Quantity [1] MWH MWh MAW MW

Currency [1] Any valid ISO 3 letter currency code, such as: DKK Danish Kroner EUR EURO NOK Norwegian Kroner RUB Russian Ruble SEK Swedish Kronor

Measure Unit Price [0..1] MWH MWh MAW MW Shall be used if a price is stated

Reserve Object [0..1] Relevant object within the market, e.g. Station group or Resource object, see Table 13 below

Direction [1] A01 Up A02 Down A03 Up and down Usage: See Table 13 below

Direction [1] Z01 Buying Z02 Selling Z03 Average Usage must be specified when implemented

Period



Interval

Qty [1] Quantity

Price [0..1] Price Usage must be specified when implemented

Reason (Interval level)

Reason Code [1] A73 Bid accepted B09 Bid not accepted

Table 12: Usage of ERRP Reserve Allocation Result Document, version 1.0




6.6.3 Dependencies

Document type

Process type

Business type

Contract type

Contract Id

Reserve object

Direction

A38 Reserve Allocation Result (Operational bids)


Z02 Frequency bias A01 Not used Not used Not used

Z03 FCR-N A01 or A02

Required Dependent on national

rules

Required

Z06 FCR-D A01 or A02

Required Dependent on national

rules

Required


A12 FRR-A A02 or A03

Not used Not used Required

A30 Tertiary reserve process, i.e. Balance regulation market

A01 Production A01 Not used Not used Required

A04 Consumption A01 or A06



A01 Production A01, A02 or A06


A04 Consumption Not used Not used

Z05, Bilateral trade

A01 Production A01 Not used Not used Not used

A04 Consumption A01 Not used Not used Not used

Table 13: Dependency matrix for ERRP Reserve Allocation Result Document, version 1.0




6.7 NEG ECAN Allocation Result Document, version 3.0

The NEG ECAN Allocation Result Document is based on the Allocation result document from the ENTSO-E ECAN IG, see [1].

6.7.1 Class diagram; NEG ECAN Allocation Result Document, version 3.0

Figure 29: Class diagram: NEG ECAN Allocation Result Document, version 3.0





Table 2: ENTSO-E documents used for trade on day-ahead and intraday markets: o 8, Day-ahead detailed sales report o 18, Intraday detailed sales report

6.7.2 Attribute usage: NEG ECAN Allocation Result Document


Reserve allocation result document

Allocation Result Document




Document Type [1] A25 Allocation result

Process Type [1]

A01 Day-ahead A19 Intraday accumulated


Sender Role [1] A11 Market operator



Receiver Role [1] Z05 Trader (non-balance responsible party) A08 Balance responsible party


Bid Time Interval [1] The beginning and ending date and time of the period covered by the document

Domain [1] Nordic area, National Area, Market Balance Area.

Subject Party [1] The Party related to the Bid in question

Subject Role [1] Z05 Trader (non-balance responsible party) A08 Balance responsible party

Allocation Time Series

Time Series Identification

[1] Unique ID of the time series

Portfolio Identification

[0..1] Identification of the portfolio (account) in question Usage must be specified when implementing.

Bid Identification [0..1] Unique ID of the bid Usage must be specified when implementing.


[0..1] Unique ID of the auction if such exist.

Business Type [1] A06 External trade without explicit capacity

In Area [1] Relevant area for the market

Out Area [1] Equal to In Area

Contract Type [1] A01 Daily A07 Intraday contract


[1] MWH MWh

Currency [0..1] ISO three digit currency code, e.g.: DKK Denmark, krone EUR European Union, Euro NOK Norway, krone SEK Sweden, krona




Shall be used if a Price Amount or a Bid Price Amount is stated

Measure Unit Price [0..1] MWH MWh Shall be used if a Price Amount or a Bid Price Amount is stated

System Bid Identification

[0..1] A system generated Bid Identification. Only used in the Bid Status Report.

Period



Interval

Pos [1] The relative position of a period within an interval

Qty [0..1] The quantity for the interval in question

Not accepted blocks will be reported without quantity Further usage must be specified when implementing.

Selling Qty [0..1] Use either Selling or Buying Qty

Zero trade will be zero value

Further usage must be specified when implementing.

Buying Qty [0..1] Use either Selling or Buying Qty

Zero trade will be zero value Further usage must be specified when implementing.

Price Amount [0..1] Price (may be negative)

Not used for block bids Further usage must be specified when implementing.

Bid Qty [0..1] Quantity from the bid Further usage must be specified when implementing.

Bid Price Amount [0..1] Price amount from the bid Further usage must be specified when implementing.

Reason

Reason Code [0..1] A73 Bid accepted B09 Bid not accepted Z18 Preliminary currency exchange rate. Nordic code. Further usage must be specified when implementing.

Table 14: Usage of NEG ECAN Allocation Result Document

6.7.3 Dependencies

Document type Process type Contract type Measure Unit Price

A25 Allocation result

A01 Day-ahead A01 Daily

A19 Intraday accumulated

A07 Intraday contract




Table 15: Dependency matrix for ECAN Reserve Allocation Result Document 6.7.4 Market Operator usage of NEG ECAN Allocation Result Document: Result time series:

Use either Selling Qty or Buying Qty element

Zero trade will be zero value either in Selling Qty or Buying Qty element Results for blocks:

Use either Selling Qty or Buying Qty element

Price Amount element is not used (note that it is actually amount, not just price)

Bid Qty and Bid Price Amount elements are not used

Not accepted blocks will be reported without quantity, only containing intervals with positions and Reason code B09




6.8 NEG ECAN Publication Document, version 1.1

The NEG ECAN Publication Document is used for summaries from all markets within the Nordic trading system. The document is based on the Publication Document from the ENTSO-E ECAN IG, see [1].

6.8.1 Class diagram; NEG ECAN Publication Document, version 1.1

Figure 30: Class diagram: NEG ECAN Publication Document, version 1.1


Table 1: ENTSO-E documents used in the Nordic trading system: o 5, FRR-A summary report o 10, Reserve option market summary report




o 15, Frequency activated reserves summary o 21, Bilateral trade report o 25, Balance regulation market price o 26, Price report o 27, Price report o 28, Activated or deactivated bids o 29, Daily exchange report o 30, Traded volume o 31, Balance regulation market price

Table 2: ENTSO-E documents used for trade on day-ahead and intraday markets: o 7, Day-ahead sales report o 9, Day-ahead summary sales report o 10, Day-ahead sales report o 12, Day-ahead sales report o 19, Intraday summary sales report o 24, Average prices report o 25, Average prices report o 26, Average prices report




6.8.2 Attribute usage; NEG ECAN Publication Document, version 1.1


NEG ECAN Publication Document

Publication Document




Document Type [1] A25 Allocation result A38 Reserve Allocation Result A44 Price document

Process Type [1] A01 Day-ahead A17 Schedule day - The process concerns the day ahead, intraday

and eventually ex-post scheduling in a single document. The schedule will be transferred within the total position including historic information (The trade balance of a party at a given time)

A19 Intraday accumulated A28 Primary reserve process, i.e. Frequency activated reserves

market A29 Secondary reserve process, i.e. FRR-A market Z04 Reserve option market (Nordic code) Z05 Bilateral trade (Nordic code)



Sender Role [1] A11 Market operator (or TSO)


[0..1] Identification of the party who is receiving the schedules Not used when the document is published at a web site

Receiver Role [0..1] A04 System operator A08 Balance responsible party A11 Market operator (NOIS) A38 Reconciliation Responsible Z05 Trader (non-balance responsible party) Not used when the document is published at a web site


Bid Time Interval [1] The beginning and ending date and time of the period covered by the document

Domain [0..1] Nordic area, National Area, Market Balance Area.

Publication Time Series

Time Series Identification

[1] Unique ID of the time series

Business Type [1] A01 Production A04 Consumption A06 External trade without explicit capacity A08 Net internal trade (ENTSO-E definition: “Net internal trade -

where the direction from out party (seller) to in party (buyer) is positive and the opposite direction is negative (with minus signs)”)


A24 Total trade (ENTSO-E definition: “A time series concerning the total of both the internal and external trades) (Usage in Sweden: The trade balance of a party at a given time)

A62 Spot Price






Z32 System price (including volume) (Nordic code)

In Area [1] Relevant area for the market

Out Area [1] The same area as “In-area” (Required in ECAN Publication Document)

Contract Type [0..1] A01 Daily A02 Weekly A07 Intraday contract Usage must be specified when implementing


[0..1] MWH MWh Shall be used when a quantity is stated

Currency [0..1] Any valid ISO 3 letter currency code, such as: DKK Danish Kroner EUR EURO NOK Norwegian Kroner RUB Russian Ruble SEK Swedish Kronor Shall be used when a price is stated

Measure Unit Price [0..1] MWH MWh Shall be used when a price is stated

Period

Time Interval [1] Time Interval

Resolution [1] Resolution

Interval

Pos [1] The relative position of a period within an interval Usage must be specified when implementing

Qty [0..1] The quantity for the interval in question Usage must be specified when implementing

Price [0..1] The price expressed per currency per unit of price measure Usage must be specified when implementing

Maximum Price [0..1] Maximum Price Usage must be specified when implementing

Minimum Price [0..1] Minimum Price Usage must be specified when implementing

Table 16: Usage of NEG ECAN Publication Document, version 1.1




6.8.3 Dependencies

Document type

Process type

Business type

Contract Type

A25 Allocation result

A01 Day-ahead A06 External trade without explicit capacity

Not used

A08 Net internal trade Not used

A19 Intraday accumulated A06 External trade without explicit capacity

Not used

A08 Net internal trade Not used

A17 Schedule day A08 Net internal trade Not used

A38 Reserve Allocation Result (Operational bids)



Required




Not used


A01 Production Not used

A04 Consumption Not used

Z05 Bilateral trade (Nordic code)



A44 Price document

A01 Day-ahead A06 External trade without explicit capacity

Not used

A19 Intraday accumulated A06 External trade without explicit capacity

Not used



Not used


Not used



Not used




Z05 Bilateral trade (Nordic code)



Table 17: Dependency matrix for NEG ECAN Publication Document, version 1.1




7 Business rules

7.1 General ground rules

The process flow assumes that a certain number of basic rules are respected. This does not include the specific rules that have been defined in an interchange agreement. These basic rules are:

1. The last valid document (latest Creation date) received before cut-off time is the valid document. 2. Reserve bids for the Balance Regulation Market can be changed until 45 minutes before the hour. 3. All version numbers shall be positive integer values and leading zeros shall be suppressed. 4. All documents received shall have an acknowledgement (acceptance, rejection or errors). 5. All the times related to energy products in the documents are expressed in Coordinated Universal

Time (the acronym of which is UTC) in compliance with ISO 8601. This is restricted to YYYY-MM-DDTHH:MMZ in order to remain in conformity with XML schema requirements.

6. All the time intervals in the documents are expressed in compliance with ISO 8601 This is restricted to YYYY-MM-DDTHH:MMZ/YYYY-MMDDTHH:MMZ. The time interval has an inclusive start time and an exclusive end time and is expressed in minutes (i.e. 00:00Z to 00:00Z is exactly a 24 hour period).

7. The time interval defined in the period class shall always be a multiple of its resolution. 8. Negative quantities for a time series are only permitted for certain categories of time series. 9. It is preferred that the quantity for a Balance responsible time series in a day-ahead and an intraday

is given in power units’ as the average value over the time interval. 10. Whenever a coded value within a document is associated with a coding scheme, the coding scheme

must always be supplied. The coding scheme is an independent attribute with a size of 3 alphanumeric characters.

11. To cancel bids, the Bid Document shall be resubmit with “0”-values in the quantity of the relevant time series.

12. In general, an update of a bid is done by sending a new document with the same bid-id. For update of a Spot Bid Document: A new document is sent with the same Document identification, an incremented Document Version and the same Bid identification.

13. One legal entity can be identified by different id’s for different purposes, apart from in Sweden. 14. All the documents use UTF-8, hence supporting all Scandinavian characters.
